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207-045
C:\Users\mdguhl\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\LCF4WGUY\2022-12-02_22065_KRU_1J-120_ProductionProfile_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 22065 KRU 1J-120 50-029-23352-00 Production Profile 02-Dec-22 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 By Meredith Guhl at 2:44 pm, Dec 14, 2022 207-045 T37372 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.12.14 14:46:17 -09'00' 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 Other: Convert ESP to GL Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 15,822 feet None feet true vertical 3,952 feet None feet Effective Depth measured 15,113 feet 8147, 8175,8370,8782 feet true vertical 3,935 feet 3578, 3585, 3630, 3698 feet Perforation depth: Tubing (size, grade, measured and true vertical depth)4.5 ''L-80 8,202' MD 3,592' TVD Packers and SSSV (type, measured and true vertical depth) PACKER BAKER PREMIER PKR 8,147' MD 3,578' TVD PACKER HRD ZXP LINER TOP PKR 8,175' MD 3,585' TVD PACKER HRD ZXP LINER TOP PKR 8,370' MD 3,630' TVD PACKER HRD ZXP LINER TOP PKR 8,772' MD 3,698' TVD SSSV NONE N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Sydney Autry Contact Name:Sydney Autry Authorized Title:Sr. Petroleum Engineer Contact Email:Sydney.Autry@cop.com Contact Phone:(907) 265-6813 Authorized Name: Authorized Signature with date: Senior Engineer: Senior Res. Engineer: Printed and Electronic Fracture Stimulation Data WINJ WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-164 508 1207 590 1203 289 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 165 165 214 144 171 10 3/4 '' 4,100' MD 2470' TV N/A Representative Daily Average Production or Injection Data Measured depth: True Vertical depth: 10240-12205, 12506-13145, 13445-14179, 14350-15113 feet 3874-3905, 3911-3930, 3921-3923, 3926-3935 feet CONDUCTOR 78 feet 20" 108' MD 108' TVD A LINER SLOTTED 6,428 feet 4 1/2 '' 15,200' MD 3936' TVD INTERMEDIATE 9,917 feet 7 5/8 '' 9,944' MD 3871' TVD SURFACE 4,070 feet Packer measured true vertical Casing Length Size MD TVD N/A Kuparuk River Field / West Sak Oil Pool Plugs measured Junk measured Burst Collapse 3. Address:P. O. Box 100360, Anchorage, Alaska 99510 50-029-23352-00-00 8. Well Name and Number:KRU 1J-120ADL 25650,ADL 25661 REPORT OF SUNDRY WELL OPERATIONS 2. Operator Name:ConocoPhillips Alaska, Inc.4. Well Class Before Work: 5. Permit to Drill Number: 207-045 GINJ SUSP SPLUG Gas Service Form 10-404 Revised 3/2020 Submit Within 30 days of Operations Sydney Autry Digitally signed by Sydney Autry Date: 2020.04.28 13:24:45 -08'00' By Samantha Carlisle at 1:38 pm, Apr 28, 2020 1J-120 Well Events Summary Date Event Summary 3/26/2020 1J-120 SI & Freeze Protected, begin evaluating option to convert to gas lift 4/3/2020 Update automation from ESP to Gas Lift in IP.21 4/6/2020 Begin downhole on slickline to convert from ESP to gas lift 4/10/2020 Complete downhole conversion from ESP to gas lift. Passing MIT-IA to 2500 psi. IA DDT completed. 4/12/2020 Gas lift blinds rolled to open and orifice plate rotated to correct metering direction. 4/18/2020 1J-120 BOL to gas lifted production. Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag:1J-120 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason; Pulled ESP Equipment, Closed Sliding Sleeves, Installed Isolation Sleeve, & Installed GL 4/10/2020 1J-120 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 19.12 Top (ftKB) 30.0 Set Depth (ftKB) 108.0 Set Depth (TVD)… 108.0 Wt/Len (l… 94.00 Grade K-55 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 30.3 Set Depth (ftKB) 4,100.0 Set Depth (TVD)… 2,469.6 Wt/Len (l… 45.50 Grade L-80 Top Thread BTC Casing Description INTERMEDIATE OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 27.4 Set Depth (ftKB) 9,944.4 Set Depth (TVD)… 3,871.2 Wt/Len (l… 29.70 Grade L80 Top Thread BTCM Casing Description D LINER LEM OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 8,164.5 Set Depth (ftKB) 8,398.0 Set Depth (TVD)… 3,636.6 Wt/Len (l… 12.60 Grade L-80 Top Thread IBTM Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 8,164.5 3,582.0 75.48 SLEEVE 5.75" ID Tie back sleeve 5.750 8,175.4 3,584.8 75.37 PACKER 5.5"x7.625" "HRD" ZXP Liner Top Packer w/ hold down slips 4.960 8,183.2 3,586.7 75.30 SBE 190-47 Casing Seal Bore Recepetacle 6.30" OD x 4.75" ID 4.750 8,202.8 3,591.8 75.11 XO BUSHING 5.5" BTC x 4.5" IBT Cross Over Bushing 3.960 8,213.8 3,594.6 75.13 NIPPLE DB Nipple 3.75" ID, 4.5" IBTM Box x Pin 3.750 8,225.1 3,597.5 75.40 HANGER LEM Above Hook Hanger 3.970 8,235.7 3,600.1 75.66 HANGER LEM Below Hook Hanger 3.930 8,394.7 3,635.9 77.45 SEAL ASSY 190-47 Non-Locating Seal Assembly 3.880 Casing Description D LINER HH OD (in) 4 1/2 ID (in) 3.48 Top (ftKB) 8,235.1 Set Depth (ftKB) 8,515.7 Set Depth (TVD)… 3,659.3 Wt/Len (l… 11.60 Grade L-80 Top Thread BTC Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 8,235.1 3,600.0 75.65 HANGER Baker Model B-1 Hook Hanger 7 5/8" x 4 1/2" (Inside csg) 5.600 8,252.0 3,604.1 76.06 HANGER Baker Model B-1 Hook Hanger 7 5/8" x 4 1/2" (Outside csg) 4.000 8,418.7 3,641.0 77.96 ECP Baker Payzone External Casing Packer 3.960 8,484.8 3,653.9 79.62 BENT JT 4 1/2" ,12.6 ppf, L-80 STL BENT joint Blank Casing 3.992 Casing Description B LINER LEM OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 8,369.7 Set Depth (ftKB) 8,815.5 Set Depth (TVD)… 3,705.4 Wt/Len (l… 12.60 Grade L80 Top Thread IBT Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 8,369.7 3,630.4 77.42 PACKER ZXP 5-1/2" x 7-5/8" Liner Top Packer TOP 5.530 8,388.4 3,634.5 77.45 SBR 109-47 Casing Seal Bore Receptacle 6.26" OD x 4.75 4.750 8,407.4 3,638.6 77.67 XO BUSHING XO Bushing 5-1/2" Hydril 563 x 4-1/2" IBT 4.500 8,663.9 3,682.1 81.60 HANGER LEM Above Hook Hanger 3.688 8,670.7 3,683.1 81.62 HANGER LEM Inside Hook Hanger 3.688 8,737.6 3,693.1 81.09 NIPPLE Camco "DB-6" Nipple, I.D. 3.562", IBT 3.562 8,770.0 3,698.2 80.75 BENT JT 4-1/2, 12.6 ppf. L-80, X/O Bent Jt. IBT Box X STL 3.958 8,812.2 3,704.9 81.17 SEAL ASSY Baker Seal Assembly 4-1/2" STL Box up 3.880 Casing Description B LINER HH OD (in) 4 1/2 ID (in) 3.48 Top (ftKB) 8,670.4 Set Depth (ftKB) 8,955.3 Set Depth (TVD)… 3,725.1 Wt/Len (l… 11.60 Grade L-80 Top Thread BTC Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 8,670.4 3,683.1 81.62 HANGER Baker Model B-1 Hook Hanger 7 5/8" x 4 1/2" (Inside csg) 5.600 8,687.2 3,685.5 81.62 HANGER Baker Model B-1 Hook Hanger 7 5/8" x 4 1/2" (Outside csg) 4.000 8,857.2 3,711.5 81.86 ECP Baker Payzone External Casing Packer 3.960 8,924.9 3,720.9 82.04 BENT JT 4 1/2" ,12.6 ppf, L-80 STL BENT joint Blank Casing 3.992 Casing Description A LINER Slotted OD (in) 4 1/2 ID (in) 3.48 Top (ftKB) 8,771.7 Set Depth (ftKB) 15,200.0 Set Depth (TVD)… 3,935.7 Wt/Len (l… 11.60 Grade L80 Top Thread BTC w/ TR Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 8,771.7 3,698.5 80.73 PACKER 5.5"x 7.63" Baker "HRD" ZXP Liner Top Pkr 5.750 8,790.7 3,701.5 80.84 NIPPLE "RS" Packoff Seal Nipple, 6.07" OD / 4.87" ID 4.870 8,793.6 3,702.0 80.89 HANGER 5.5" X 7.63" "Flex-Lock" Liner Hgr, 6.59" OD/ 4.85 4.850 8,803.4 3,703.5 81.04 SBE 190-47 Seal Bore Ext, 6.29" OD / 4.75" ID 4.750 15,113.5 3,935.4 90.39 Swell Packer Swell Packer #2 3.960 15,174.8 3,935.4 89.54 Swell Packer Swell Packer #1 3.960 Tubing Strings Tubing Description Tubing RWO 2017 String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 22.3 Set Depth (ft… 8,145.5 Set Depth (TVD) (… 3,577.3 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 22.3 22.3 0.00 Hanger Tubing Hanger, Vetco-Gray MB222A offset 10 3/4 x 4 1/2 w/false bowl 3.900 7,753.8 3,478.3 74.60 GaugeBaker SureSENS Gauge3.938 7,822.6 3,496.6 74.59 Sliding Sleeve CMU (Closed) Gas Venting Sliding Sleeve CMU (with position #3 ACCESS profile for keys), 3.875" X Profile, Access ( Closed 4/9/2020 ) 3.958 1J-120, 4/28/2020 11:11:43 AM Vertical schematic (actual) A LINER Slotted; 8,771.7- 15,200.0 SLOTS; 14,350.0-15,113.0 SLOTS; 13,445.0-14,179.0 SLOTS; 12,506.0-13,145.0 SLOTS; 10,240.0-12,205.0 INTERMEDIATE; 27.4-9,944.4 B LINER HH; 8,670.4-8,955.3 B LINER LEM; 8,369.7-8,815.5 D LINER HH; 8,235.1-8,515.7 D LINER LEM; 8,164.5-8,398.0 MULE SHOE; 8,163.5 LOCATOR; 8,162.6 PACKER; 8,147.0 PBR; 8,134.0 Seal Assembly; 8,133.1 Locator; 8,132.3 Sliding Sleeve - CMU (Closed); 8,068.2 No-Go 3.80" Sub; 8,013.2 Profile Sub; 7,992.4 Annular Connection Port; 7,953.8 ACCESS ISOLATION SLEEVE; 7,953.0 Motor Shroud/Centralizer; 7,917.6 XO Enlarging (Tubing); 7,914.5 Gauge; 7,753.7 GAS LIFT; 7,685.6 SURFACE; 30.3-4,100.0 GAS LIFT; 3,652.4 CONDUCTOR; 30.0-108.0 Hanger; 22.4 KUP PROD KB-Grd (ft) 32.29 Rig Release Date 6/16/2007 1J-120 ... TD Act Btm (ftKB) 15,822.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292335200 Wellbore Status PROD Max Angle & MD Incl (°) 92.84 MD (ftKB) 13,392.03 WELLNAME WELLBORE Annotation Last WO: End Date 9/21/2017 H2S (ppm) 20 Date 1/25/2019 Comment SSSV: NONE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 7,853.6 3,504.8 74.79 Sliding Sleeve CMD (Closed) Gas Venting Sliding Sleeve CMD (with position #4 ACCESS profile for keys), 3.875" X Profile, (Closed 4/9/2020) 3.958 7,917.6 3,521.3 75.31 Motor Shroud/Centraliz er Motor Shroud / Centralizer, Access, 5-1/2" FJL Pin x 5-1/2" FJL Pin ( Pulled 11/28/2018 ) 4.900 7,953.8 3,530.4 75.54 Annular Connection Port Annular Connection Port, Access, 5-1/2" FJL Box x 4-1/2" Vam Top Box Set 4.5" Access ISO Sleeve OAL = 135.5" 11/28/2018 3.840 7,992.4 3,540.0 75.77 Profile Sub B-Profile Sub, Access, 4-1/2", 12.6#, L-80, TXP Box x Box 3.956 8,013.2 3,545.1 75.89 No-Go 3.80" Sub No-Go 3.80" Sub, Access, 4-1/2, 12.6#, L-80, TXP Box x Pin 3.800 8,068.2 3,558.4 75.94 Sliding Sleeve - CMU (Closed) CMU Sliding Sleeve, 3.813" DB profile, Baker (4/9/2020 )3.810 8,132.3 3,574.0 75.78 Locator Locater Sub, Baker, GBH-22 (bottom of the locator spaced out 1.59') 3.880 8,133.1 3,574.2 75.78 Seal Assembly Baker 192-47 Seal Assembly 4-1/2", 12.6#, L-80, IBTM Box 3.870 Tubing Description Stacker Packer RWO 2017 String Ma… 4.51 ID (in) 3.98 Top (ftKB) 8,134.0 Set Depth (ft… 8,199.3 Set Depth (TVD) (… 3,590.9 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 8,134.0 3,574.5 75.77 PBR PBR, Baker, 80-47 with 6.69" scoop guide, 4-1/2" 12.6# TC-II Pin down 4.750 8,147.0 3,577.7 75.64 PACKER Premier Packer, Baker, 659-387, 4-1/2", 12.6# TC-II Box x Pin 3.870 8,162.6 3,581.6 75.49 LOCATOR Locater (bottom of the locator spaced out 1') 3.980 8,163.5 3,581.8 75.49 MULE SHOE Mule Shoe Joint 3.980 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in) 7,953.0 3,530.2 75.54 ACCESS ISOLATION SLEEVE 4 1/2" ACCESS ISOLATION SLEEVE W/ 3.85" PACKING (11.25' OAL) 4/10/20203.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 10,240.0 12,205.0 3,873.8 3,905.2 WS A2, 1J-120 5/17/2007 32.0 SLOTS 2.5"x .125",4 circumferencial rows/ft 3" centers staggered 18 deg 12,506.0 13,145.0 3,911.2 3,930.0 WS A2, 1J-120 5/17/2007 32.0 SLOTS 2.5"x .125",4 circumferencial rows/ft 3" centers staggered 18 deg 13,445.0 14,179.0 3,920.6 3,922.9 WS A2, 1J-120 5/17/2007 32.0 SLOTS 2.5"x .125",4 circumferencial rows/ft 3" centers staggered 18 deg 14,350.0 15,113.0 3,925.6 3,935.5 WS A2, 1J-120 5/17/2007 32.0 SLOTS 2.5"x .125",4 circumferencial rows/ft 3" centers staggered 18 deg Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in)Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com 1 3,652.4 2,307.1 Camco KBG-2 1 ESP GLV BK 0.188 1,449.0 4/10/2020 2 7,685.6 3,460.3 Camco KBG-2 1 ESP OVBK 0.3130.0 4/10/2020 Notes: General & Safety End Date Annotation 11/13/2017 NOTE: or inflow performance issue are suspected 11/13/2017 NOTE: Well shut-in repeatedly-high motor temperature, and a restriction in the pump intake 9/21/2017 NOTE: WO 1J-120, 4/28/2020 11:11:45 AM Vertical schematic (actual) A LINER Slotted; 8,771.7- 15,200.0 SLOTS; 14,350.0-15,113.0 SLOTS; 13,445.0-14,179.0 SLOTS; 12,506.0-13,145.0 SLOTS; 10,240.0-12,205.0 INTERMEDIATE; 27.4-9,944.4 B LINER HH; 8,670.4-8,955.3 B LINER LEM; 8,369.7-8,815.5 D LINER HH; 8,235.1-8,515.7 D LINER LEM; 8,164.5-8,398.0 MULE SHOE; 8,163.5 LOCATOR; 8,162.6 PACKER; 8,147.0 PBR; 8,134.0 Seal Assembly; 8,133.1 Locator; 8,132.3 Sliding Sleeve - CMU (Closed); 8,068.2 No-Go 3.80" Sub; 8,013.2 Profile Sub; 7,992.4 Annular Connection Port; 7,953.8 ACCESS ISOLATION SLEEVE; 7,953.0 Motor Shroud/Centralizer; 7,917.6 XO Enlarging (Tubing); 7,914.5 Gauge; 7,753.7 GAS LIFT; 7,685.6 SURFACE; 30.3-4,100.0 GAS LIFT; 3,652.4 CONDUCTOR; 30.0-108.0 Hanger; 22.4 KUP PROD 1J-120 ... WELLNAME WELLBORE Annotation Last WO: 9/21/2017 End Date 10/5/2017 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Convert ESP to GL 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 Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 15,822'NONE Casing Collapse Conductor Surface Intermediate A Liner SLOTTED 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Sydney Autry Contact Name:Sydney Autry Senior. Petroleum Engineer Contact Email: Contact Phone:(907) 265-6813 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Name: Authorized Title:Sydney.Autry@cop.com Authorized Signature: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 10240-12205, 12506-13145, 13445-14179, 14350-15113 3874-3905, 3911-3930, 3921- 3923, 3926-3935 4.500'' L-80 PACKER - BAKER PREMIER PACKER PACKER - HRD ZXP LINER TOP PACKER PACKER - BAKER HRD ZXP LINER TOP PACKER PACKER - HRD ZXP LINER TOP PACKER SSSV - NONE 8147 MD and 3578 TVD 8175 MD and 3585 TVD 8370 MD and 3630 TVD 8772 MD AND 3698 TVD N/A 4/11/2020 8146' Packers and SSSV MD (ft) and TVD (ft):Packers and SSSV Type: 6,428' 4 1/2 15,200' 3936' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9,917' 7 5/8 9,944' 3871' 78' 20'' 108' 108' 4,070' 10 3/4 4,100' 2470' Length Size MD TVD Burst NONE P. O. Box 100360, Anchorage, Alaska 99510 50-029-23352-00 KRU 1J-120 ADL 25650, ADL 25661 Kuparuk River Field / West Sak Oil Pool PRESENT WELL CONDITION SUMMARY 3,952' 15,113' 3,935' 947 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ConocoPhillips Alaska, Inc.207-045 Perforate Reppair Well Exploratory Stratigraphic Development Service BOP TestMechanical Integrity Test Location Clearance No No Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Sydney Autry Digitally signed by Sydney Autry Date: 2020.04.13 16:31:43 -08'00' N By Samantha Carlisle at 5:21 pm, Apr 13, 2020 320-164 DSR-4/13/2020 X 10-404 DLB 4/14/2020 X -00 VTL 4/15/20 equ ed Yes C 4/15/2020 dt s 4/15/2020 JLC 4/15/2020 Sydney Autry Senior Drillsite Petroleum Engineer ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501 Phone: (907) 265-6813 April 06, 2020 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, AK 99501 Dear Commissioner, KRU 1J-120 is an ESP lifted well that has struggled to achieve expected rates due to the high viscosity of the oil and emulsions stabilized from the produced sand. The decision was made to convert 1J-120 to back-up gas lift to evaluate the production (premised until the watercut rises enough to reduce the effects of viscosity & emulsions on the pump). The down hole conversion work is in progress and includes pulling the pump & motor, closing all sleeves intended to assist in gas venting up the IA, and performing the appropriate MITs. Once complete, the status of the well will be “packered gas lift”. Enclosed you will find 10-403 forms for 1J-120, 1J-120L1 & 1J-120L2 (PTD 207-045, 207-046, & 207-047) and a summary of well events. Sincerely, Sydney Autry Senior Drillsite Petroleum Engineer ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501 Phone: (907) 265-6813 Sydney Autry Digitally signed by Sydney Autry Date: 2020.04.13 16:33:05 -08'00' pp) closing all sleeves intended to assist in gas venting up the IA, ve e Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag:1J-120 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Replace ESP Pump, Packoff, and Slip Stop. 1/18/2020 1J-120 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 19.12 Top (ftKB) 30.0 Set Depth (ftKB) 108.0 Set Depth (TVD)… 108.0 Wt/Len (l… 94.00 Grade K-55 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 30.3 Set Depth (ftKB) 4,100.0 Set Depth (TVD)… 2,469.6 Wt/Len (l… 45.50 Grade L-80 Top Thread BTC Casing Description INTERMEDIATE OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 27.4 Set Depth (ftKB) 9,944.4 Set Depth (TVD)… 3,871.2 Wt/Len (l… 29.70 Grade L80 Top Thread BTCM Casing Description D LINER LEM OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 8,164.5 Set Depth (ftKB) 8,398.0 Set Depth (TVD)… 3,636.6 Wt/Len (l… 12.60 Grade L-80 Top Thread IBTM Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 8,164.5 3,582.0 75.48 SLEEVE 5.75" ID Tie back sleeve 5.750 8,175.4 3,584.8 75.37 PACKER 5.5"x7.625" "HRD" ZXP Liner Top Packer w/ hold down slips 4.960 8,183.2 3,586.7 75.30 SBE 190-47 Casing Seal Bore Recepetacle 6.30" OD x 4.75" ID 4.750 8,202.8 3,591.8 75.11 XO BUSHING 5.5" BTC x 4.5" IBT Cross Over Bushing 3.960 8,213.8 3,594.6 75.13 NIPPLE DB Nipple 3.75" ID, 4.5" IBTM Box x Pin 3.750 8,225.1 3,597.5 75.40 HANGER LEM Above Hook Hanger 3.970 8,235.7 3,600.1 75.66 HANGER LEM Below Hook Hanger 3.930 8,394.7 3,635.9 77.45 SEAL ASSY 190-47 Non-Locating Seal Assembly 3.880 Casing Description D LINER HH OD (in) 4 1/2 ID (in) 3.48 Top (ftKB) 8,235.1 Set Depth (ftKB) 8,515.7 Set Depth (TVD)… 3,659.3 Wt/Len (l… 11.60 Grade L-80 Top Thread BTC Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 8,235.1 3,600.0 75.65 HANGER Baker Model B-1 Hook Hanger 7 5/8" x 4 1/2" (Inside csg) 5.600 8,252.0 3,604.1 76.06 HANGER Baker Model B-1 Hook Hanger 7 5/8" x 4 1/2" (Outside csg) 4.000 8,418.7 3,641.0 77.96 ECP Baker Payzone External Casing Packer 3.960 8,484.8 3,653.9 79.62 BENT JT 4 1/2" ,12.6 ppf, L-80 STL BENT joint Blank Casing 3.992 Casing Description B LINER LEM OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 8,369.7 Set Depth (ftKB) 8,815.5 Set Depth (TVD)… 3,705.4 Wt/Len (l… 12.60 Grade L80 Top Thread IBT Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 8,369.7 3,630.4 77.42 PACKER ZXP 5-1/2" x 7-5/8" Liner Top Packer TOP 5.530 8,388.4 3,634.5 77.45 SBR 109-47 Casing Seal Bore Receptacle 6.26" OD x 4.75 4.750 8,407.4 3,638.6 77.67 XO BUSHING XO Bushing 5-1/2" Hydril 563 x 4-1/2" IBT 4.500 8,663.9 3,682.1 81.60 HANGER LEM Above Hook Hanger 3.688 8,670.7 3,683.1 81.62 HANGER LEM Inside Hook Hanger 3.688 8,737.6 3,693.1 81.09 NIPPLE Camco "DB-6" Nipple, I.D. 3.562", IBT 3.562 8,770.0 3,698.2 80.75 BENT JT 4-1/2, 12.6 ppf. L-80, X/O Bent Jt. IBT Box X STL 3.958 8,812.2 3,704.9 81.17 SEAL ASSY Baker Seal Assembly 4-1/2" STL Box up 3.880 Casing Description B LINER HH OD (in) 4 1/2 ID (in) 3.48 Top (ftKB) 8,670.4 Set Depth (ftKB) 8,955.3 Set Depth (TVD)… 3,725.1 Wt/Len (l… 11.60 Grade L-80 Top Thread BTC Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 8,670.4 3,683.1 81.62 HANGER Baker Model B-1 Hook Hanger 7 5/8" x 4 1/2" (Inside csg) 5.600 8,687.2 3,685.5 81.62 HANGER Baker Model B-1 Hook Hanger 7 5/8" x 4 1/2" (Outside csg) 4.000 8,857.2 3,711.5 81.86 ECP Baker Payzone External Casing Packer 3.960 8,924.9 3,720.9 82.04 BENT JT 4 1/2" ,12.6 ppf, L-80 STL BENT joint Blank Casing 3.992 Casing Description A LINER Slotted OD (in) 4 1/2 ID (in) 3.48 Top (ftKB) 8,771.7 Set Depth (ftKB) 15,200.0 Set Depth (TVD)… 3,935.7 Wt/Len (l… 11.60 Grade L80 Top Thread BTC w/ TR Liner Details Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com Nominal ID (in) 8,771.7 3,698.5 80.73 PACKER 5.5"x 7.63" Baker "HRD" ZXP Liner Top Pkr 5.750 8,790.7 3,701.5 80.84 NIPPLE "RS" Packoff Seal Nipple, 6.07" OD / 4.87" ID 4.870 8,793.6 3,702.0 80.89 HANGER 5.5" X 7.63" "Flex-Lock" Liner Hgr, 6.59" OD/ 4.85 4.850 8,803.4 3,703.5 81.04 SBE 190-47 Seal Bore Ext, 6.29" OD / 4.75" ID 4.750 15,113.5 3,935.4 90.39 Swell Packer Swell Packer #2 3.960 15,174.8 3,935.4 89.54 Swell Packer Swell Packer #1 3.960 Tubing Strings Tubing Description Tubing RWO 2017 String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 22.3 Set Depth (ft… 8,145.5 Set Depth (TVD) (… 3,577.3 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 22.3 22.3 0.00 Hanger Tubing Hanger, Vetco-Gray MB222A offset 10 3/4 x 4 1/2 w/false bowl 3.900 7,753.8 3,478.3 74.60 Gauge Baker SureSENS Gauge 3.938 7,822.6 3,496.6 74.59 Sliding Sleeve CMU Gas Venting Sliding Sleeve CMU (with position #3 ACCESS profile for keys), 3.875" X Profile, Access ( Opened 12/10/2018 ) 3.958 7,853.6 3,504.8 74.79 Sliding Sleeve CMD Gas Venting Sliding Sleeve CMD (with position #4 ACCESS profile for keys), 3.875" X Profile, (Opened 12/10/2018) 3.958 1J-120, 4/9/2020 10:05:16 AM Vertical schematic (actual) A LINER Slotted; 8,771.7- 15,200.0 SLOTS; 14,350.0-15,113.0 SLOTS; 13,445.0-14,179.0 SLOTS; 12,506.0-13,145.0 SLOTS; 10,240.0-12,205.0 INTERMEDIATE; 27.4-9,944.4 B LINER HH; 8,670.4-8,955.3 B LINER LEM; 8,369.7-8,815.5 D LINER HH; 8,235.1-8,515.7 D LINER LEM; 8,164.5-8,398.0 MULE SHOE; 8,163.5 LOCATOR; 8,162.6 PACKER; 8,147.0 PBR; 8,134.0 Seal Assembly; 8,133.1 Locator; 8,132.3 Sliding Sleeve - CMU; 8,068.2 No-Go 3.80" Sub; 8,013.2 Profile Sub; 7,992.4 Annular Connection Port; 7,953.8 Motor Shroud/Centralizer; 7,917.6 ACCESS MOTOR; 7,904.0 XO Enlarging (Tubing); 7,914.5 Gauge; 7,753.7 GAS LIFT; 7,685.6 SURFACE; 30.3-4,100.0 GAS LIFT; 3,652.4 CONDUCTOR; 30.0-108.0 Hanger; 22.4 KUP PROD KB-Grd (ft) 32.29 Rig Release Date 6/16/2007 1J-120 ... TD Act Btm (ftKB) 15,822.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292335200 Wellbore Status PROD Max Angle & MD Incl (°) 92.84 MD (ftKB) 13,392.03 WELLNAME WELLBORE Annotation Last WO: End Date 9/21/2017 H2S (ppm) 20 Date 1/25/2019 Comment SSSV: NONE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 7,917.6 3,521.3 75.31 Motor Shroud/Centraliz er Motor Shroud / Centralizer, Access, 5-1/2" FJL Pin x 5-1/2" FJL Pin ( Pulled 11/28/2018 ) 4.900 7,953.8 3,530.4 75.54 Annular Connection Port Annular Connection Port, Access, 5-1/2" FJL Box x 4-1/2" Vam Top Box Set 4.5" Access ISO Sleeve OAL = 135.5" 11/28/2018 3.840 7,992.4 3,540.0 75.77 Profile Sub B-Profile Sub, Access, 4-1/2", 12.6#, L-80, TXP Box x Box 3.956 8,013.2 3,545.1 75.89 No-Go 3.80" Sub No-Go 3.80" Sub, Access, 4-1/2, 12.6#, L-80, TXP Box x Pin 3.800 8,068.2 3,558.4 75.94 Sliding Sleeve - CMU CMU Sliding Sleeve, 3.813" DB profile, Baker (Closed 11/28/2018 )3.810 8,132.3 3,574.0 75.78 Locator Locater Sub, Baker, GBH-22 (bottom of the locator spaced out 1.59') 3.880 8,133.1 3,574.2 75.78 Seal Assembly Baker 192-47 Seal Assembly 4-1/2", 12.6#, L-80, IBTM Box 3.870 Tubing Description Stacker Packer RWO 2017 String Ma… 4.51 ID (in) 3.98 Top (ftKB) 8,134.0 Set Depth (ft… 8,199.3 Set Depth (TVD) (… 3,590.9 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 8,134.0 3,574.5 75.77 PBR PBR, Baker, 80-47 with 6.69" scoop guide, 4-1/2" 12.6# TC-II Pin down 4.750 8,147.0 3,577.7 75.64 PACKER Premier Packer, Baker, 659-387, 4-1/2", 12.6# TC-II Box x Pin 3.870 8,162.6 3,581.6 75.49 LOCATOR Locater (bottom of the locator spaced out 1') 3.980 8,163.5 3,581.8 75.49 MULE SHOE Mule Shoe Joint 3.980 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in) 7,904.0 3,517.8 75.20 ACCESS MOTOR 3.80" ACCESS ESP MOTOR (50' OAL)7/19/2019 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 10,240.0 12,205.0 3,873.8 3,905.2 WS A2, 1J-120 5/17/2007 32.0 SLOTS 2.5"x .125",4 circumferencial rows/ft 3" centers staggered 18 deg 12,506.0 13,145.0 3,911.2 3,930.0 WS A2, 1J-120 5/17/2007 32.0 SLOTS 2.5"x .125",4 circumferencial rows/ft 3" centers staggered 18 deg 13,445.0 14,179.0 3,920.6 3,922.9 WS A2, 1J-120 5/17/2007 32.0 SLOTS 2.5"x .125",4 circumferencial rows/ft 3" centers staggered 18 deg 14,350.0 15,113.0 3,925.6 3,935.5 WS A2, 1J-120 5/17/2007 32.0 SLOTS 2.5"x .125",4 circumferencial rows/ft 3" centers staggered 18 deg Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in)Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com 1 3,652.4 2,307.1 Camco KBG-2 1 ESPDMYBK0.000 0.0 10/25/2017 2 7,685.6 3,460.3 Camco KBG-2 1 ESPDMYBK0.000 0.0 4/6/2020 Notes: General & Safety End Date Annotation 11/13/2017 NOTE: or inflow performance issue are suspected 11/13/2017 NOTE: Well shut-in repeatedly-high motor temperature, and a restriction in the pump intake 9/21/2017 NOTE: WO 1J-120, 4/9/2020 10:05:18 AM Vertical schematic (actual) A LINER Slotted; 8,771.7- 15,200.0 SLOTS; 14,350.0-15,113.0 SLOTS; 13,445.0-14,179.0 SLOTS; 12,506.0-13,145.0 SLOTS; 10,240.0-12,205.0 INTERMEDIATE; 27.4-9,944.4 B LINER HH; 8,670.4-8,955.3 B LINER LEM; 8,369.7-8,815.5 D LINER HH; 8,235.1-8,515.7 D LINER LEM; 8,164.5-8,398.0 MULE SHOE; 8,163.5 LOCATOR; 8,162.6 PACKER; 8,147.0 PBR; 8,134.0 Seal Assembly; 8,133.1 Locator; 8,132.3 Sliding Sleeve - CMU; 8,068.2 No-Go 3.80" Sub; 8,013.2 Profile Sub; 7,992.4 Annular Connection Port; 7,953.8 Motor Shroud/Centralizer; 7,917.6 ACCESS MOTOR; 7,904.0 XO Enlarging (Tubing); 7,914.5 Gauge; 7,753.7 GAS LIFT; 7,685.6 SURFACE; 30.3-4,100.0 GAS LIFT; 3,652.4 CONDUCTOR; 30.0-108.0 Hanger; 22.4 KUP PROD 1J-120 ... WELLNAME WELLBORE Annotation Last WO: 9/21/2017 End Date 10/5/2017 1J-120 Well Events Summary Date Event Summary 3/26/2020 1J-120 SI & Freeze Protected, begin evaluating option to convert to gas lift 4/3/2020 Update automation from ESP to Gas Lift in IP.21 4/6/2020 Begin downhole on slickline to convert from ESP to gas lift (3-5 days expected duration) 7(i 4Jr.:4 'V STATE OF ALASKA ( 0l AL*OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS h ^ UGG " 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing E Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other:Install ESP 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. ment Develo Exploratory❑ P lorato ry ❑ 207-045 3.Address: P. 0. Box 100360,Anchorage,Alaska Stratigraphic ❑ Service ❑ 6.API Number: 99510 50-029-23352-00 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 1J-120 ADL 25661,25650 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 15,822 feet Plugs measured None feet true vertical 3,952 feet Junk measured None feet Effective Depth measured 15200' feet Packer measured 8147,8175, feet 8370,8772 true vertical 3935' feet true vertical 3578,3585, feet 3630,3699 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 feet 20" 108' MD 108'TVD SURFACE 4,070 feet 10-3/4" 4,100' MD 2470"TVD INTERMEDIATE 9,917 feet 7-5/8" 9,944' MD 3871"TVD A LINER SLOTTED 6,428 feet 4-1/2" 15,200'MD 3936"TVD Tubing(size,grade,measured and true vertical depth) 4.5" L-80 8,146'MD 3,577'TVD Packers and SSSV(type,measured and true vertical depth) PACKER-PREMIER PACKER,BAKER,659-387 8,147' MD 3,578'ND PACKER-"HRD"ZXP LINER TOP PACKER 8175' MD 3585'ND PACKER-ZXP LINER TOP PACKER TOP 8370' MD 3630'TVD PACKER-"HRD"ZXP LINER TOP PACKER 8772' MD 3699'ND SSSV-NONE N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: SCANNED DEC 1 4 2017 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 250 688 267 929 178 Subsequent to operation: 0 0 0 275 140 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 2 Exploratory ❑ Development 2 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑✓ Gas 0 WDSPL 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: N/A Contact Name: Andrew Beat Authorized Name: Andrew Beat Contact Email: Andrew.T.Beat@cop.com Authorized Title: Senior Wells Engineer Authorized Signature: Contact Phone: (907)265-6341 s 11 Date: 110�1��17 Form 10-404 Revised 4/2017 '749/007 ATL `(}l`fil t! RBD IS '1 `, Utt 1 7 `U'7 Submit Original Only 1-- e • :.„„ 0 Operations Summary (with Timelog Depths) 1J-120 ConocaPhitIips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/7/2017 9/7/2017 2.00 MIRU MOVE RURD P Release Doyon 14 off 1J-115.Skid.rig 0.0 0.0 18:00 20:00 to center of carrier. 9/7/2017 9/7/2017 1.00 MIRU MOVE MOB P Move rig off 1J-115 and stage on pad. 0.0 0.0 20:00 21:00 9/7/2017 9/7/2017 2.50 MIRU MOVE RURD P Lay matting boards around 1J-120. 0.0 0.0 21:00 23:30 Sim-ops/Change out Gen#3 and highline breakers. 9/7/2017 9/8/2017 0.50 MIRU MOVE MOB P Move rig to 1J-120. 0.0 0.0 23:30 00:00 9/8/2017 9/8/2017 2.25 MIRU MOVE MOB P Spot rig over 1J-120. Level and shim 0.0 0.0 00:00 02:15 rig. 9/8/2017 9/8/2017 0.50 MIRU MOVE RURD P PJSM-Skid rig into drilling position. 0.0 0.0 02:15 02:45 9/8/2017 9/8/2017 3.25 MIRU MOVE RURD P Rig up rig floor.Rig up beaver slide. 0.0 0.0 02:45 06:00 Spot and berm cuttings tank.Rig up cuttings chute.Spot mud lab and break room. Prep pits to take on water. 9/8/2017 9/8/2017 2.50 MIRU WELCTL RURD P Rig up flow back tanks.Take on fresh 0.0 0.0 06:00 08:30 water to pits.Flush pits and check for leaks. Accept rig at 06:00 hrs 9-8-17 9/8/2017 9/8/2017 0.50 MIRU WELCTL SFTY P Hold pre-spud meeting. 0.0 0.0 08:30 09:00 9/8/2017 9/8/2017 1.00 MIRU WELCTL MPSP P PJSM-Pick up lubricator.Rig up 0.0 0.0 09:00 10:00 lubricator pressure lines to cellar.Test lubricator to 2500 psi.Leak at o-ring in tree cap.Change out o-ring.Test lubricator to 2500 psi.Pull BPV. Tubing pressure=925 psi. Bleed pressure off lubricator.Master valve leaking.Work valve. Rig down lubricator. 9/8/2017 9/8/2017 0.75 MIRU WELCTL RURD P Rig up lines in cellar to flow back 0.0 0.0 10:00 10:45 tanks. 9/8/2017 9/8/2017 0.25 MIRU WELCTL SEQP P Test lines from rig to flow back tanks 0.0 0.0 10:45 11:00 to 250/2500 psi. 9/8/2017 9/8/2017 2.00 MIRU WELCTL OTHR P Load and heat 8.6 ppg 3%KCL 0.0 0.0 11:00 13:00 seawater to pits. 9/8/2017 9/8/2017 2.00 MIRU WELCTL OTHR P Bleed off IA pressure from 540 psi to 0 0.0 0.0 13:00 15:00 psi.Shut in IA and bleed tubing pressure from 850 psi to 0 psi. 9/8/2017 9/8/2017 5.50 MIRU WELCTL OTHR P Heat and load a total of 340 bbls of 0.0 0.0 15:00 20:30 8.6 ppg 3%KCL seawater in pits.Sim- ops/Work on MP2's 9/8/2017 9/8/2017 0.25 MIRU WELCTL OTHR P Bleed pressure off tubing from 225 psi 0.0 0.0 20:30 20:45 to 0 psi.Bleed pressure off IA from 300 psi to 0 psi. 9/8/2017 9/8/2017 1.00 MIRU WELCTL KLWL P Pump 140 bbls 140°8.6 ppg 3%KCL 0.0 0.0 20:45 21:45 seawater down IA with no returns to kill tank.8 bpm/1340 psi.Bullhead with 150 bbls 65°8.6 ppg 3% seawater.5 bpm/370 psi. 9/8/2017 9/8/2017 0.50 MIRU WELCTL KLWL P Bullhead 150 bbls 140°8.6 ppg 3% 0.0 0.0 21:45 22:15 KCL seawater down tubing.8 bpm/1070 psi. 9/8/2017 9/8/2017 0.50 MIRU WELCTL OWFF P Monitor well.IA and tubing on 0.0 0.0 22:15 22:45 vacuum.Sim-ops/Blow down lines. Page 1/16 Report Printed: 9/26/2017 • • 02. 0Operations Summary (with Timelog Depths) s 1J-120 ConocorPhit hps Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code -Activity Code Time P-T-X Operation (ftKB) End.Depth(ftKB)' 9/8/2017 9/8/2017 0.50 MIRU WHDBOP MPSP P Rig up and set type HP BPV. 0.0 0.0 22:45 23:15 9/8/2017 9/8/2017 0.50 MIRU WHDBOP OTHR P Rig up LRS.Test lines to 500 psi. 0.0 0.0 23:15 23:45 Pump 10 bbl diesel cap down IA.Rig down LRS 9/8/2017 9/9/2017 0.25 MIRU WHDBOP NUND P Bleed pressure off hanger void.Prep 0.0 0.0 23:45 00:00 for nipple down of tree.Pump 5 bbls 3%KCL seawater down IA every 30 mins. 9/9/2017 9/9/2017 1.00 MIRU WHDBOP NUND P Nipple down tree and adapter flange. 0.0 0.0 00:00 01:00 Inspect hanger threads.Good.Install caps on penetrators. 9/9/2017 9/9/2017 2.00 MIRU WHDBOP NUND P Nipple up BOPE.Make up kill line. 0.0 0.0 01:00 03:00 Charge up accumulator.Prep rig floor for BOPE test. 9/9/2017 9/9/2017 0.50 MIRU WHDBOP MPSP P Rig up and set test dart. 0.0 0.0 03:00 03:30 9/9/2017 9/9/2017 1.50 MIRU WHDBOP RURD P PJSM-Rig up to test BOPE.Make up 0.0 0.0 03:30 05:00 4 1/2"test joint and TD. 9/9/2017 9/9/2017 1.00 MIRU WHDBOP RURD P PJSM-Fill BOPE w/water.Purge air 0.0 0.0 05:00 06:00 from system.Perform body test 9/9/2017 9/9/2017 9.00 MIRU WHDBOP BOPE P Test BOPE with 4 1/2"test joint.to . 0.0 0.0 06:00 15:00 250/2500 psi for 5 min's each.Test#1 -Lower 2 7/8"x 5"VBR's.Test#2- Upper 2 7/8"x 5"VBR's,valves 1,12,13,14 and 2"kill Demco.Test#3- Kill HCR.Test#4-Manual kill,manual choke.Test#5-Annular,valves 9,11 . Test#6-Blind rams,valves 5,8,10. Test#7-Blind rams,lower!BOP, valves 4,6,7.Trouble shoot leak in system.Pump up gauge protector, and grease manual kill valve.Test#8- Blind rams,valve 2 and dart valve. Perform accumulator test:System pressure=2950 psi,pressure after closure=1650 psi,200 psi attained=38 sec,full pressure attained=196 sec.6 Nitrogen bottles average=2016 psi. Test witness waived by AOGCC Rep Jeff Jones. 9/9/2017 9/9/2017 6.00 MIRU WHDBOP BOPE T Change out blind rams and manual kill 0.0 0.0 15:00 21:00 valve.Sim-ops/Change out test dart. 9/9/2017 9/9/2017 1.00 MIRU WHDBOP BOPE T PJSM-Fill BOPE w/water.Purge air 0.0 0.0 21:00 22:00 from system.Perform body test.Door seal on driller side blind rams leaking. 9/9/2017 9/9/2017 1.50 MIRU WHDBOP RGRP T Bleed pressure off.Pump out BOPE. 0.0 0.0 22:00 23:30 Open and inspect and clean door seal. Sim-ops/Test 4 1/2"FOSV and 4" HT38 FOSV to 250/2500 psi for 5 min's each. 9/9/2017 9/10/2017 0.50 MIRU WHDBOP RURD T PJSM-Fill BOPE w/water.Purge air 0.0 0.0 23:30 00:00 from system. Page 2/16 Report Printed: 9/26/2017 • • . ,„,..„...t., Operations Summary (with Timelog Depths) 01.4 1J-120 Conocs tii ps Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/10/2017 9/10/2017 2.00 MIRU WHDBOP BOPE T Test#9-blind rams.Pressure 0.0 0.0 00:00 02:00 dropping off.Pump water out of stack and check for leak at blind rams.No visual sign of leakage.Bleed off pressure. Install 4 1/2"test joint.Close lower VBR's.Test to 2500 psi. Pressure dropping off with no visual leakage.Suspect that leak path is the tubing hanger.Consult with Wells Superintendant. 9/10/2017 9/10/2017 1.00 MIRU WHDBOP BOPE P Pull test joint.Test#10-4"FOSV.Test 0.0 0.0 02:00 03:00 #11-valve 2,Test#12-valve 3.Test #13-4"dart valve.Test#14-Super choke and manual choke. 1500 psi bleed down. 9/10/2017 9/10/2017 1.00 MIRU WHDBOP RURD P Rig down test equipment..Blow down 0.0 0.0 03:00 04:00 lines. 9/10/2017 9/10/2017 1.00 MIRU WHDBOP OTHR T Pump out BOPE.Mobilize x-o's to rig 0.0 0.0 04:00 05:00 floor. 9/10/2017 9/10/2017 2.00 MIRU WHDBOP WAIT T Obtain approval from AOGCC rep Jeff 0.0 0.0 05:00 07:00 Jones to pull and lay down hanger and set test plug. 9/10/2017 9/10/2017 0.75 MIRU WHDBOP MPSP T PJSM-Rig up and pull test dart. 0.0 0.0 07:00 07:45 Inspect and reset. 9/10/2017 9/10/2017 1.75 MIRU WHDBOP BOPE T Rig up test equipment.Test#16- 0.0 0.0 07:45 09:30 Perform rolling pressure test on blind rams 250/2500 psi 10 min.Test#17- Perform rolling pressure test on upper VBR's,manual kill and choke valves to verify integrity of surface equipment. Witnessed by AOGCC Rep Jeff Jones. 9/10/2017 9/10/2017 3.25 MIRU WHDBOP OTHR P Rig up T bar and engage test dart. 0.0 0.0 09:30 12:45 Unseat poppet on BPV.Bleed off gas through BPV. 9/10/2017 9/10/2017 0.50 MIRU WHDBOP MPSP P Pull BPV.Monitor well.On vacuum. 0.0 0.0 12:45 13:15 9/10/2017 9/10/2017 0.50 MIRU WHDBOP RURD P PJSM-Rig up to pull hanger.Make up 0.0 0.0 13:15 13:45 landing joint to top drive.Set down 5K. BOLDS. 9/10/2017 9/10/2017 1.50 MIRU WHDBOP THGR P Pull hanger-Pick up to 135K.Stage 8,178.0 8,148.0 13:45 15:15 up to 210K. Leave pipe in tension and apply steam to well head.Hanger free. Pull hanger to rig floor.PU=115K SO=70K. 9/10/2017 9/10/2017 0.50 MIRU WHDBOP PULL P PJSM-Lay down hanger and single 8,148.0 8,148.0 15:15 15:45 joint below. .Make up test plug to completion string.RIH and set test plug 9/10/2017 9/10/2017 0.25 MIRU WHDBOP RURD T Rig up test equipment. 8,148.0 8,148.0 15:45 16:00 9/10/2017 9/10/2017 1.00 MIRU WHDBOP BOPE P Test#18-blind rams to 250/2500 psi 5 8,148.0 8,148.0 16:00 17:00 mins each.Test#19-upper VBR's, manual kill,and choke valves and 4" FOSV w/4 1/2"test joint.Witnessed by AOGCC rep Jeff Jones. 9/10/2017 9/10/2017 0.50 MIRU WHDBOP RURD T Rig down test equipment.BLow down 8,148.0 8,148.0 17:00 17:30 choke and kill lines-Sim-ops/Hang TEC wire sheave in derrick. Page 3/16 Report Printed: 9/26/2017 • • 0 Operations Summary (with Timelog Depths) ,t 1J-120 Conoco Phimps Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB). 9/10/2017 9/10/2017 1.00 MIRU WHDBOP RURD T Pull and lay down test plug and x-o's. 8,148.0 8,115.0 17:30 18:30 9/10/2017 9/10/2017 1.50 COMPZN RPCOMP RURD P Rig up to pull completion.Pick up 8,115.0 8,115.0 18:30 20:00 single joint tubing and make up to string. 9/10/2017 9/11/2017 4.00 COMPZN RPCOMP PULL P POOH standing back 4 1/2"IBT 8,115.0 5,788.0 20:00 00:00 completion string from 8115'MD to 5788'MD.Spool TEC wire,remove single channel Cannon clamps every joint.SLM. . 9/11/2017 9/11/2017 8.50 COMPZN RPCOMP PULL P POOH standing back 4 1/2"tubing 5,788.0 0.0 00:00 08:30 from 5788'MD to surface.Remove single channel Cannon clamps on each connection.SLM Recover 257 Cannon clamps and 3 SS bands. 9/11/2017 9/11/2017 0.75 COMPZN RPCOMP RURD P Clean and clear rig floor 0.0 0.0 08:30 09:15 9/11/2017 9/11/2017 4.75 COMPZN RPCOMP RURD P Remove old TEC wire from spooler 0.0 0.0 09:15 14:00 and install new spool.Lay down old Cannon clamps. Rig up to run 4 1/2" Rigless ESP completion. 9/11/2017 9/11/2017 2.50 COMPZN RPCOMP ALFT P PJSM-Pick up 4 1/2"12.6#L-80 IBTM 0.0 395.0 14:00 16:30 Rigless ESP completion.Make up seal assy,sliding sleeve Access motor shroud/centralizer assy and 2 sliding sleeves. 9/11/2017 9/11/2017 1.50 COMPZN RPCOMP ALFT P Pick up Baker SureSENS gauge. 395.0 420.0 16:30 18:00 Make up TEC wire and test to 5000 psi. Install dual channel Grippy clamps on each connection. 9/11/2017 9/11/2017 3.00 COMPZN RPCOMP RCST P RIH out of derrick 4 1/2"tubing from 420.0 1,349.0 18:00 21:00 420'MD to 1349'MD. Drift each stand w/3.81"drift. 9/11/2017 9/11/2017 1.75 COMPZN RPCOMP ALFT P PJSM-Mobilize slickline tools to rig 1,349.0 1,349.0 21:00 22:45 floor.Make up 3.80"drift w/3.83" centralizer. 9/11/2017 9/12/2017 1.25 COMPZN RPCOMP ALFT P RIH w/slickline.Unable to drift past 1,349.0 1,349.0 22:45 00:00 GLM at 929'MD.POOH w/slickline. 9/12/2017 9/12/2017 1.00 COMPZN RPCOMP ALFT T Continue to POOH with slickline. 1,349.0 1,349.0 00:00 01:00 Break out drift and MU lead impression block(LIB). 9/12/2017 9/12/2017 1.00 COMPZN RPCOMP ALFT T RIH with LIB,tag at 928'SLM and 1,349.0 1,349.0 01:00 02:00 POOH. 9/12/2017 9/12/2017 0.50 COMPZN RPCOMP ALFT T Inspect LIB at surface and LIB 1,349.0 1,349.0 02:00 02:30 indicates over torqued connection. Stand back slickline. 9/12/2017 9/12/2017 2.00 COMPZN RPCOMP TRIP T TOOH standing back the 4-1/2"tubing 1,349.0 400.0 02:30 04:30 in the derrick from 1349'to 400'MD removing cannon clamps and rabbiting the tubing with a 3.83"OD drift. 9/12/2017 9/12/2017 1.00 COMPZN RPCOMP PULD T Inspect GLM connections and visual 400.0 400.0 04:30 05:30 inspection look as if the bottom pup joint of the GLM was over torqued. Lay down the GLM and replace with upper GLM which a DV was installed in. 9/12/2017 9/12/2017 0.50 COMPZN RPCOMP TRIP T TIH from 400'to 493'MD installing 400.0 493.0 05:30 06:00 cannon clamps. Page 4/16 Report Printed: 9/26/2017 • • . ;: .1.., .„ Operations Summary (with Timelog Depths) mm 1 J-120 itii�ss Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time. End Time Dur(hr) Phase Op.Code Activity Code Time P-T-X Operation (ftKB) End Depth(5KB) 9/12/2017 9/12/2017 0.75 COMPZN RPCOMP ALFT T PJSM. RU slickline and MU 3.833" 493.0 493.0 06:00 06:45 OD drift. 9/12/2017 9/12/2017 0.25 COMPZN RPCOMP ALFT P RIH with drift to no-go sub.The Drift 493.0 493.0 06:45 07:00 hung up likely in the new GLM and fell through when the Spang jars closed. PU and tool string weigh was gone. POOH and confirmed that the 3.80" section of the drift had stripped the 3/4"Sucker Rod threads and had gone down hole. 9/12/2017 9/12/2017 3.00 COMPZN RPCOMP SLKL T Attempt to fish the drift tool string was 493.0 493.0 07:00 10:00 unsuccessful.Rig down Slick Line. 9/12/2017 9/12/2017 2.00 COMPZN RPCOMP TRIP T Rack back the ESP completion in the 493.0 120.0 10:00 12:00 derrick to the IBT x TXP crossover. RD the Tec wire and unplug the ESP cable. Found the drift stuck in the no- go sub(unable to remove)and the lower portion of the drift. 9/12/2017 9/12/2017 1.00 COMPZN RPCOMP PULD T Lay down the joint of tubing and 120.0 65.0 12:00 13:00 sliding sleeve assembly. Leave 1 joint of tubing and the seal assembly in the hole for slickline operations 9/12/2017 9/12/2017 0.75 COMPZN RPCOMP SLKL T RU slickline and MU overshot tool 65.0 65.0 13:00 13:45 string. 9/12/2017 9/12/2017 1.25 COMPZN RPCOMP SLKL T RIH with overshot tool string to 2400' 65.0 65.0 13:45 15:00 SLM but ran out of string weight. POOH. 9/12/2017 9/12/2017 4.50 COMPZN RPCOMP SLKL T Add additional weight bars to the tool 65.0 65.0 15:00 19:30 string. RIH to 4900'SLM but ran out of string weight. POOH 9/12/2017 9/12/2017 0.50 COMPZN RPCOMP SLKL T RD slickline 65.0 65.0 19:30 20:00 9/12/2017 9/12/2017 0.50 COMPZN RPCOMP PULD T Lay down the joint of tubing and the 65.0 0.0 20:00 20:30 seal assembly. 9/12/2017 9/12/2017 2.00 COMPZN RPCOMP RURD T Move ESP completion from the ODS 0.0 0.0 20:30 22:30 to the DS of the derrick. Move the Tec wire spooler from in front of the beaver slide. Lay down the 5-1/2"power tongs. Mobilize the 4-1/2"power tong and 2-7/8"handling equipment to the rig floor. RU the 4-1/2"power tongs and 2-7/8"elevators. 9/12/2017 9/12/2017 0.25 COMPZN RPCOMP BHAH T PU and MU 3-5/8"short catch 0.0 7.0 22:30 22:45 overshot assembly with 3,313"grapple to catch fishing neck on the 3.80"Drift. 9/12/2017 9/13/2017 1.25 COMPZN RPCOMP PULD T RIH with 3-5/8"overshot assembly on 7.0 630.0 22:45 00:00 2-7/8"EUE 8rd tubing to 630'and MU 2-7/8"x 4-1/2"crossover. 9/13/2017 9/13/2017 0.50 COMPZN RPCOMP RURD T Change elevators and power tong dies 630.0 630.0 00:00 00:30 from 2-7/8"to 4-1/2". 9/13/2017 9/13/2017 6.50 COMPZN RPCOMP TRIP T TIH with 3-5/8"overshot assembly on 630.0 8,148.0 00:30 07:00 4-1/2"IBTM tubing from 630'to 8148' MD. Page 5/16 Report Printed: 9/26/2017 . • 0 0Operations Summary (with Timelog Depths) 1J-120 ConocoPhillips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth '1)Start Time End Time 'ra Dur(hr) Phase Op Code Activity Code Time P-T X Operation (ftKB) End Depth(ftKS), 9/13/2017 9/13/2017 1.50 COMPZN RPCOMP FISH T Obtain parameter: PU=103K,SO= 8,148.0 8,204.0 07:00 08:30 76K and 2 BPM= 180 psi. Wash down from 8148'MD to tag at 8204' MD with 1-2K down and the pump pressure increased to 480 psi. PU 5' and pressure remaining constant. Pumps off. 9/13/2017 9/13/2017 6.50 COMPZN RPCOMP TRIP T TOOH with 3-5/8"overshot assembly 8,204.0 721.0 08:30 15:00 standing back the 4-1/2"tubing from 8204'to 721'MD. 9/13/2017 9/13/2017 0.25 COMPZN RPCOMP RURD T Change elevators from 4-1/2"to 2- 721.0 721.0 15:00 15:15 7/8". 9/13/2017 9/13/2017 1.00 COMPZN RPCOMP PULD T POOH laying down 2-7/8"EUE 8rd 721.0 7.0 15:15 16:15 tubing. 9/13/2017 9/13/2017 0.25 COMPZN RPCOMP BHAH T Lay down overshot with fish. 7.0 0.0 16:15 16:30 9/13/2017 9/13/2017 0.75 COMPZN RPCOMP BHAH T Clear and clean the floor. 0.0 0.0 16:30 17:15 9/13/2017 9/13/2017 0.75 COMPZN RPCOMP RURD T Change elevators from 2-7/8"to 4- 0.0 0.0 17:15 18:00 1/2". Ensure equipment in the pipe shed is in the correct order. 9/13/2017 9/13/2017 0.25 COMPZN RPCOMP SFTY T PJSM for running completion. 0.0 0.0 18:00 18:15 9/13/2017 9/13/2017 0.75 COMPZN RPCOMP ALFT T 'PU and MU the seal assembly, 1 joint 0.0 120.0 18:15 19:00 of 4-1/2"tubing,sliding sleeve assembly and 1 joint of 4-1/2"tubing. Attempt to MU 4-1/2"TXP x IBT crossover but the 4-1/2"power tongs were unable to MU the connection. 9/13/2017 9/13/2017 1.50 COMPZN RPCOMP RURD T RD the 4-1/2"power tongs,move the 120.0 120.0 19:00 20:30 Tec wire spooler,unload the 4-1/2" power tongs from the rig floor, mobilize the 5-1/2"power tongs to the rig floor and RU he 5-1/2"power tongs. 9/13/2017 9/13/2017 0.50 COMPZN RPCOMP ALFT P PU and MU 4-1/2"TXP x IBT 120.0 156.0 20:30 21:00 crossover and MU no-go sub/B-profile sub assembly. 9/13/2017 9/13/2017 0.50 COMPZN RPCOMP ALFT T PU and MU annular connection port 156.0 180.0 21:00 21:30 assembly and MU ESP cable pothead. 9/13/2017 9/13/2017 1.25 COMPZN RPCOMP ALFT T PU and MU motor shroud/centralizer 180.0 360.0 21:30 22:45 assembly,CMU/CMD sliding sleeve assembly and SureSENS gauge carrier assembly. Installing cannon clamps as needed. 9/13/2017 9/13/2017 0.50 COMPZN RPCOMP ALFT T MU SureSENS gauge with Tec wire 360.0 360.0 22:45 23:15 and PT to 5000 psi for 10 minutes (good test). Installing cannon clamps as needed. 9/13/2017 9/13/2017 0.25 COMPZN RPCOMP ALFT T PU and MU GLM with DV assembly. 360.0 430.0 23:15 23:30 Installing cannon clamps as needed. 9/13/2017 9/14/2017 0.50 COMPZN RPCOMP TRIP T TIH with ESP completion on4-1/2" 430.0 735.0 23:30 00:00 IBTM tubing from derrick to 735'MD at midnight. Spooling ESP cable/Tec wire and Installing cannon clamps as needed. Page 6/16 Report Printed: 9/26/2017 Operations Summary (with Timelog Depths) 0 1J-120 • ConocoPhilliips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(EKE) 9/14/2017 9/14/2017 0.50 COMPZN RPCOMP TRIP T Continue to TIH with ESP completion 735.0 1,076.0 00:00 00:30 on 4-1/2"tubing from 735'to 1076' MD. Spooling ESP cable/Tec wire and Installing cannon clamps as needed. 9/14/2017 9/14/2017 0.25 COMPZN RPCOMP SFTY T PJSM to RU slickline. 1,076.0 1,076.0 00:30 00:45 9/14/2017 9/14/2017 1.00 COMPZN RPCOMP ALFT T Mobilize slickline tools to the rig floor 1,076.0 1,076.0 00:45 01:45 and RU slickline. 9/14/2017 9/14/2017 1.75 COMPZN RPCOMP ALFT T MU three sections of 3.83"OD drift. 1,076.0 1,076.0 01:45 03:30 but unable to get past crossover to the tubing. Drift connections have a sharp shoulder. Break out the middle section. MU two section and notice a slight bend. Break apart the two sections. 9/14/2017 9/14/2017 0.75 COMPZN 'RPCOMP ALFT T RIH with a single 3'section of 3.83" 1,076.0 1,076.0 03:30 04:15 OD drift to tag at 150'SLM. POOH and lay down drift. 9/14/2017 9/14/2017 0.75 COMPZN RPCOMP ALFT T MU 3.835"OD gauge ring with two 3' 1,076.0 1,076.0 04:15 05:00 sections of 3.80"OD drift. RIH to tag at 651'SLM at the GLM. POOH and lay down the drift assembly. MU 3.86" OD LIB. 9/14/2017 9/14/2017 0.25 COMPZN RPCOMP ALFT T RIH with LIB,tag at 651'and POOH. 1,076.0 1,076.0 05:00 05:15 9/14/2017 9/14/2017 0.25 COMPZN RPCOMP ALFT T LIB had slight scuff marks. Break out 1,076.0 1,076.0 05:15 05:30 LIB and MU 3.835"OD gauge ring. 9/14/2017 9/14/2017 0.25 COMPZN RPCOMP ALFT T RIH with 3.835"OD gauge ring,tag at 1,076.0 1,076.0 05:30 05:45 651'and POOH. 9/14/2017 9/14/2017 1.50 COMPZN RPCOMP ALFT T Break out 3.835"OD gauge ring and 1,076.0 1,076.0 05:45 07:15 MU 3.80"OD drift. RIH with 3.80"OD drift,hung up at 400'SLM,worked through and continue to 952'SLM. POOH and RD slickline. 9/14/2017 9/14/2017 1.75 COMPZN RPCOMP TRIP T TOOH from 1076'to 400'MD and lay 1,076.0 400.0 07:15 09:00 down the GLM. 9/14/2017 9/14/2017 0.50 COMPZN RPCOMP ALFT T MU the GLM and RU slickline. 400.0 430.0 09:00 09:30 9/14/2017 9/14/2017 0.50 COMPZN RPCOMP ALFT T MU 3.835"OD drift,RIH and hung up 430.0 430.0 09:30 10:00 at 11'SLM. 9/14/2017 9/14/2017 0.50 COMPZN RPCOMP ALFT T POOH and change to 3.833'OD drift. 430.0 430.0 10:00 10:30 9/14/2017 9/14/2017 1.00 COMPZN RPCOMP ALFT T RIH with 3.833"OD drift,tag at 220' 430.0 430.0 10:30 11:30 SLM. 9/14/2017 9/14/2017 2.00 COMPZN RPCOMP ALFT T POOH and change to a 3.80"OD drift. 430.0 430.0 11:30 13:30 While making up the drift it was • noticed that the drift was damaged. MU two sections of 3.833"OD drift with a knuckle joint in between. 9/14/2017 9/14/2017 0.75 COMPZN RPCOMP ALFT T RIH with 3.833"OD drifts to tag at 430.0 430.0 13:30 14:15 220'SLM,work through to 228'SLM and POOH. 9/14/2017 9/14/2017 0.25 COMPZN RPCOMP ALFT T Lay down the drift assembly and PU 430.0 430.0 14:15 14:30 the Access motor assembly. 9/14/2017 9/14/2017 1.25 COMPZN RPCOMP ALFT T RIH with the Access motor assembly 430.0 430.0 14:30 15:45 to bottom,latch in and POOH. Service the motor and seals. RD slickline. Page 7/16 Report Printed: 9/26/2017 0 • • 1. 0 Operations Summary (with Timelog Depths) 1J-120 conoco4 ho ips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(EKE). 9/14/2017 9/14/2017 1.25'COMPZN RPCOMP ALFT T PU and MU both GLM's with a joint of 430.0 490.0 15:45 17:00 tubing in between. RU slickline and MU Access motor assembly. Drift through both GLM's and POOH. 9/14/2017 9/14/2017 0.25 COMPZN RPCOMP ALFT T RD slickline. 490.0 490.0 17:00 17:15 9/14/2017 9/14/2017 0.25 COMPZN RPCOMP ALFT T Lay down the GLM's and joint of 490.0 400.0 17:15 17:30 tubing. 9/14/2017 9/14/2017 1.25 COMPZN RPCOMP ALFT T RU slickline and MU Access motor 400.0 400.0 17:30 18:45 assembly. RIH and set the motor/seals. PT the connection. Release from the assembly and POOH. 9/14/2017 9/14/2017 1.50 COMPZN RPCOMP ALFT T PU and MU the pump assembly. RIH 400.0 400.0 18:45 20:15 with pump assembly,set and POOH. 9/14/2017 9/14/2017 1.50 COMPZN RPCOMP ALFT T PU and MU pickoff assembly. RIH, 400.0 400.0 20:15 21:45 set the pack off and POOH. Attempt to PT but it would not hold pressure 9/14/2017 9/14/2017 0.25 COMPZN RPCOMP ALFT T MU GS,RIH,spang down,no 400.0 400.0 21:45 22:00 movement and POOH. 9/14/2017 9/14/2017 1.25 COMPZN RPCOMP ALFT T MU GS,RIH,engage pack off,POOH 400.0 400.0 22:00 23:15 and no pack off. Re-pin the GS,RIH, engage pack off, POOH and recovered the pack off. 9/14/2017 9/15/2017 0.75 COMPZN RPCOMP ALFT T Redress the upper section of the pack 400.0 400.0 23:15 00:00 off and standing valve. 9/15/2017 9/15/2017 0.25 COMPZN RPCOMP ALFT T Continue to redress the upper section 400.0 400.0 00:00 00:15 of the pack off and standing valve. 9/15/2017 9/15/2017 0.25 COMPZN RPCOMP ALFT T RIH with pack off,set and POOH. 400.0 400.0 00:15 00:30 9/15/2017 9/15/2017 1.00 COMPZN RPCOMP ALFT T RU to PT,fill the tubing with 8.6 ppg 400.0 400.0 00:30 01:30 seawater with 3%KCL,and purge the air. PT the pack off to 2000 psi for 10 minutes(good test). Bleed off the pressure,blow down and RD pressure testing equipment. 9/15/2017 9/15/2017 0.50 COMPZN RPCOMP ALFT T MU and RIH with tubing stop. Set on 400.0 400.0 01:30 02:00 top of pack off, POOH and RD slickline. 9/15/2017 9/15/2017 2.00 COMPZN RPCOMP TRIP T MU GLM with DV and TIH with ESP 400.0 1,349.0 02:00 04:00 completion on 4-1/2"IBTM tubing from derrick from 400'to 1349'MD. Spooling ESP cable/Tec wire and installing cannon clamps as needed. 9/15/2017 9/15/2017 0.25 COMPZN RPCOMP ALFT P Perform electrical checks on the ESP 1,349.0 1,349.0 04:00 04:15 cable and Tec wire(good test on both). 9/15/2017 9/15/2017 1.25 COMPZN RPCOMP TRIP P Continue to TIH with ESP completion 1,349.0 2,266.0 04:15 05:30 on 4-1/2"IBTM tubing from derrick from 1349'to 2266'MD. Spooling ESP cable/Tec wire and installing cannon clamps as needed. 9/15/2017 9/15/2017 0.50 COMPZN RPCOMP ALFT P RU slickline. 2,266.0 2,266.0 05:30 06:00 9/15/2017 9/15/2017 1.00 COMPZN RPCOMP ALFT P RIH with 3.80"OD drift and 3.83"OD 2,266.0 2,266.0 06:00 07:00 centralizer to 1800'SLM and POOH. 9/15/2017 9/15/2017 0.50 COMPZN RPCOMP ALFT P RD slickline. 2,266.0 2,266.0 07:00 07:30 Page 8/16 Report Printed: 9/26/2017 r S Operations Summary (with Timelog Depths) 1J-120 ConocoPhillips „,ixsk3 Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr)'. Phase Op Code Activity Code Time P-T-X Operation (EKE) End.Depth(ftKB) 9/15/2017 9/15/2017 2.00 COMPZN RPCOMP TRIP P Continue to TIH with ESP completion 2,266.0 3,178.0 07:30 09:30 on 4-1/2"IBTM tubing from derrick. from 2266'to 3178'MD. Spooling ESP cable/Tec wire and installing cannon clamps as needed. 9/15/2017 9/15/2017 0.25 COMPZN RPCOMP ALFT P Perform electrical checks on the ESP 3,178.0 3,178.0 09:30 09:45 cable and Tec wire(good test on both). 9/15/2017 9/15/2017 2.25 COMPZN RPCOMP TRIP P Continue to TIH with ESP completion 3,178.0 4,107.0 09:45 12:00 on 4-1/2"IBTM tubing from derrick from 3178'to 4107'MD. Spooling ESP cable/Tec wire and installing cannon clamps as needed. 9/15/2017 9/15/2017 0.25 COMPZN RPCOMP TRIP P Perform electrical checks on the ESP 4,107.0 4,107.0 12:00 12:15 cable and Tec wire(good test on both). 9/15/2017 9/15/2017 1.25 COMPZN RPCOMP TRIP P Continue to TIH with ESP completion 4,107.0 5,144.0 12:15 13:30 on 4-1/2"IBTM tubing from derrick from 4107'to 5144'MD. Spooling ESP cable/Tec wire and installing cannon clamps as needed. 9/15/2017 9/15/2017 3.50 COMPZN RPCOMP ALFT P Unload the ESP reel from the spooling 5,144.0 5,144.0 13:30 17:00 unit and load in a new ESP reel into the spooling unit. Splice the ESP cable together. While splicing,RU slickline,drift down to 1000'SLM with 3.83"drift, POOH and RD slickline. Perform electrical checks on the ESP cable and Tec wire(good test on both). 9/15/2017 9/15/2017 2.00 COMPZN RPCOMP TRIP P Continue to TIH with ESP completion 5,144.0 5,510.0 17:00 19:00 on 4-1/2"IBTM tubing from derrick from 5144'to 5510'MD. Spooling ESP cable/Tec wire and installing cannon clamps as needed. Had to replace joints 160,161 and 170. 9/15/2017 9/15/2017 0.25 COMPZN RPCOMP ALFT P Perform electrical checks on the ESP 5,510.0 5,510.0 19:00 19:15 cable and Tec wire(good test on both). 9/15/2017 9/15/2017 3.75 COMPZN RPCOMP TRIP P Continue to TIH with ESP completion 5,510.0 6,612.0 19:15 23:00 on 4-1/2"IBTM tubing from derrick from 5510'to 6612'MD. Spooling ESP cable/Tec wire and installing cannon clamps as needed.Had to replace joints 172, 173, 179, 181, 184 and 196. 9/15/2017 9/16/2017 1.00 COMPZN RPCOMP ALFT P RU slickline.PU and MU 3.80"OD 6,612.0 6,612.0 23:00 00:00 drift and 3.83"OD centralizer. RIH with drift assembly to 1800'SLM. 9/16/2017 9/16/2017 0.75 COMPZN RPCOMP ALFT P POOH and lay down drift assembly. 6,612.0 6,612.0 00:00 00:45 RD slickline. 9/16/2017 9/16/2017 1.25 COMPZN RPCOMP TRIP P Continue to TIH with ESP completion 6,612.0 7,531.0 00:45 02:00 on 4-1/2"IBTM tubing from derrick from 6612'to 7531'MD. Spooling ESP cable/Tec wire and installing cannon clamps as needed. 9/16/2017 9/16/2017 0.25 COMPZN RPCOMP ALFT P Perform electrical checks on the ESP 7,531.0 7,531.0 02:00 02:15 cable and Tec wire(good test on both). Page 9/16 Report Printed: 9/26/2017 • • 0.. 4 Operations Summary (with Timelog Depths) tw 1J-120 cccdPhitltps • Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth ''.Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB). 9/16/2017 9/16/2017 0.75 COMPZN RPCOMP TRIP P Continue to TIH with ESP completion 7,531.0 7,994.0 02:15 03:00 on 4-1/2"IBTM tubing from derrick from 7531'to 7994'MD. Spooling ESP cable/Tec wire and Installing cannon clamps as needed. 9/16/2017 9/16/2017 0.50 COMPZN RPCOMP PUTB P Continue to RIH with ESP completion 7,994.0 8,160.0 03:00 03:30 on 4-1/2"IBTM tubing from pipe shed from 7994' to 8160'MD(PU= 120K and SO=72K). Spooling ESP cable/Tec wire and installing cannon clamps as needed. 9/16/2017 9/16/2017 1.50 COMPZN RPCOMP HOSO T Continue to RIH from 8160'to tag at 8,160.0 8,183.0 03:30 05:00 8183'MD with 10K down. Work the pipe and got down to 8192'MD. PU to 8167'MD,attempt to work past 8183' MD but unable to. 9/16/2017 9/16/2017 1.00 COMPZN RPCOMP WAIT T Discuss options with town. 8,183.0 8,183.0 05:00 06:00 9/16/2017 9/16/2017 5.00 COMPZN RPCOMP HOSO T PU to 8167'MD,make 1/4 right hand 8,183.0 8,162.0 06:00 11:00 turn,SO and tag at 8172'MD. Work the pipe but keep tagging at 8172'MD. Make 3/4 right hand turn,work the pipe and work down to tag at 8183' MD. PU to 8162'MD, Kelly up,work the pipe but unable to get past 8172' MD. 9/16/2017 9/16/2017 0.50 COMPZN RPCOMP WAIT T Discuss options with town. 8,162.0 8,162.0 11:00 11:30 9/16/2017 9/16/2017 0.50 COMPZN RPCOMP HOSO T Continue to work the pipe to get past 8,162.0 8,172.0 11:30 12:00 8172'MD. Put two additional 1/4 right hand turns,work the pipe but unable to get past 8172'MD. 9/16/2017 9/16/2017 1.00 COMPZN RPCOMP CIRC T Pump 103 bbls of 8.7 ppg brine with 1 8,172.0 8,172.0 12:00 13:00 drum of Baralube into the IA. 9/16/2017 9/16/2017 1.25 COMPZN RPCOMP HOSO T Continue to work the pipe but unable 8,172.0 8,162.0 13:00 14:15 to get past 8172'MD. Test the ESP cable and the cable is grounded out. 9/16/2017 9/16/2017 1.00 COMPZN RPCOMP PULL T POOH with ESP completion from 8,162.0 7,840.0 14:15 15:15 8172'to 7840'MD laying to 41'joints of 4-1/2"tubing. Spooling ESP cable/Tec wire and removing cannon clamps as needed. 9/16/2017 9/17/2017 8.75 COMPZN RPCOMP TRIP T TOOH with ESP completion from 7,840.0 2,997.0 15:15 00:00 7840'to 2997'MD at midnight. Spooling ESP cable/Tec wire, removing cannon clamps as needed and taking electrical reading every 10 stands. 9/17/2017 9/17/2017 3.25 COMPZN RPCOMP TRIP T Continue to TOOH with ESP 2,997.0 400.0 00:00 03:15 completion from 2997'to 400'MD. Spooling ESP cable/Tec wire, removing cannon clamps as needed and taking electrical reading every 10 stands. 9/17/2017 9/17/2017 2.75 COMPZN RPCOMP ALFT T RU HES slickline. Pull the tubing 400.0 400.0 03:15 06:00 stop,equalize the pack off,pull the pack off,pull the pump assembly and pull the motor/seal assembly. Page 10/16 Report Printed: 9/26/2017 0,, Operations Summary (with Timelog Depths) . t 1J-120 Conor Phiiihps. Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End,Depth(ftKB)', 9/17/2017 9/17/2017 1.00 COMPZN RPCOMP ALFT T While attempting to pull the motor/seal 400.0 400.0 06:00 07:00 assembly the slickline parted above the wind wall. Stop the job and assess the situation. 9/17/2017 9/17/2017 1.50 COMPZN RPCOMP ALFT T PJSM. RD slickline and remove the 400.0 400.0 07:00 08:30 broken slickline. 9/17/2017 9/17/2017 0.50 COMPZN RPCOMP WAIT T Wait for lower slickline sheave to 400.0 400.0 08:30 09:00 arrive. 9/17/2017 9/17/2017 0.50 COMPZN RPCOMP ALFT T RU slickline,pull slickline tools,lay 400.0 400.0 09:00 09:30 down tool and RD slickline. 9/17/2017 9/17/2017 0.50 COMPZN RPCOMP ALFT T Clear the rig floor of slickline tools. 400.0 400.0 09:30 10:00 9/17/2017 9/17/2017 1.50 COMPZN RPCOMP PULL T Lay down a joint of 4-1/2"tubing. ESP 400.0 222.0 10:00 11:30 cable armor damaged at 372'MD(pup above gauge mandrel). RD SureSENS gauge and Tec wire. Lay down a joint of 4-1/2"tubing,gas venting sliding sleeve CMD and gas venting sliding sleeve CMU. ESP cable armor damaged at 273'MD(gas venting sliding sleeve CMU). Lay down a joint of 4-1/2"tubing. 9/17/2017 9/17/2017 1.00 COMPZN RPCOMP ALFT T PJSM. MU GS pulling tool with the 222.0 222.0 11:30 12:30 traveling blocks. Latch into the motor assembly with the GS pulling tool,PU 3-4K but motor would not pull free. Chain down the assembly. PU to 6.5K and the motor pulled free. RD GS pulling tool. 9/17/2017 9/17/2017 1.00 COMPZN RPCOMP ALFT T Service the motor seal and place the 222.0 222.0 12:30 13:30 motor/seal assembly into a 40'joint of 4-1/2"tubing in the mouse hole. 9/17/2017 9/17/2017 1.00 COMPZN RPCOMP PULL T Lay down the motor shroud/centralizer 222.0 0.0 13:30 14:30 assembly,annular connection port assembly,B-profile/no-go assembly, CMU assembly and sea assembly. 9/17/2017 9/17/2017 2.00 COMPZN RPCOMP RURD T RD the Tec wire sheave. Clear and 0.0 0.0 14:30 16:30 clean the floor. 9/17/2017 9/17/2017 1.00 COMPZN RPCOMP BHAH T Mobilize fishing tools to the rig floor. 0.0 0.0 16:30 17:30 9%17/2017 9/17/2017 0.50 COMPZN RPCOMP RURD T PJSM. Hang the motor assembly with 0.0 0.0 17:30 18:00 4.5"shroud joint off the super tugger in the derrick to access the iron roughneck . 9/17/2017 9/17/2017 0.75 COMPZN RPCOMP BHAH T PU and MU BHA#2-cleanout 0.0 65.0 18:00 18:45 assembly. 9/17/2017 9/18/2017 5.25 COMPZN RPCOMP TRIP T TIH with BHA#2 to 7600'MD at 65.0 7,600.0 18:45 00:00 midnight. 9/18/2017 9/18/2017 2.00 COMPZN RPCOMP SLPC T Slip and cut 52'of drilling line. 7,600.0 7,600.0 00:00 02:00 9/18/2017 9/18/2017 0.50 COMPZN RPCOMP PULD T Continue to RIH with BHA#2 on 4- 7,600.0 7,872.0 02:00 02:30 1/2"R3 tubing from the pipe shed from 7600'to 7872'MD. 9/18/2017 9/18/2017 0.25 COMPZN RPCOMP SFTY T Kick while tripping drill. Held AAR with 7,872.0 7,872.0 02:30 02:45 the crew. 9/18/2017 9/18/2017 0.25 COMPZN RPCOMP PULD P Continue to RIH with BHA#2 on 4- 7,872.0 8,164.0 02:45 03:00 1/2"R3 tubing from the pipe shed from 7872'to 8164'MD. 9/18/2017 9/18/2017 0.25 COMPZN RPCOMP PULD P MU crossover,a joint of DP and the 8,164.0 8,164.0 03:00 03:15 top drive. Page 11/16 Report Printed: 9/26/2017 S 0 Operations Summary (with Timelog Depths) 1J-120 ''-„',: -' CcxxxoPhillips J-120 hitilps Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time -. Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/18/2017 9/18/2017 0.50 COMPZN RPCOMP WASH P Obtain parameters: PU=100K,SO= 8,164.0 8,190.0 03:15 03:45 72K and 4 BPM=20 psi. Wash down from 8164'to 8190'MD. PU 3'and fill the IA with 40 bbls to flush the backside. 9/18/2017 9/18/2017 0.25 COMPZN RPCOMP PULD P Break out the top drive,lay down the 8,190.0 8,164.0 03:45 04:00 joint of DP and break out the crossover. Blow down the top drive. 9/18/2017 9/18/2017 1.00 COMPZN RPCOMP PULD P POOH with BHA#2 laying down 4- 8,164.0 7,600.0 04:00 05:00 1/2"R3 tubing. 9/18/2017 9/18/2017 5.00 COMPZN RPCOMP TRIP P TOOH with BHA#2 from 8164'to 65' 7,600.0 65.0 05:00 10:00 MD • 9/18/2017 9/18/2017 0.50 COMPZN RPCOMP BHAH P Lay down BHA#2-cleanout 65.0 0.0 10:00 10:30 assembly 9/18/2017 9/18/2017 1.00 COMPZN RPCOMP BHAH P Clean and clear the rig floor. 0.0 0.0 10:30 11:30 9/18/2017 9/18/2017 0.50 COMPZN RPCOMP PUTB P PU and MU mule shoe joint and 0.0 74.0 11:30 12:00 Premier packer/PBR assembly. 9/18/2017 9/18/2017 7.25 COMPZN RPCOMP RCST P TIH with packer assembly on 4-1/2" 74.0 7,849.0 12:00 19:15 IBTM tubing from the derrick from 74' to 7849'MD. Note: Had to replace joints#39,40, 114&115 for galled threads. 9/18/2017 9/18/2017 0.75 COMPZN RPCOMP PUTB P RIH with the packer assembly on 4- 7,849.0 8,173.0 19:15 20:00 1/2"IBTM tubing from the pipe shed from 7489'to 8173'MD(PU=97K and SO=70K). 9/18/2017 9/18/2017 0.25 COMPZN RPCOMP RURD P Change elevators to 4"DP. MU 8,173.0 8,173.0 20:00 20:15 crossover,DP pup,a joint of DP and the top drive 9/18/2017 9/18/2017 0.25 COMPZN RPCOMP HOSO P SO to 8207'MD with 10K down and 8,173.0 8,206.0 20:15 20:30 PU 1'. 9/18/2017 9/18/2017 1.00 COMPZN RPCOMP PACK P Drop the 29/32"setting ball and pump 8,206.0 8,206.0 20:30 21:30 to seat at 1 BPM. Pressure up to 2200 psi to set the Premier packer. SO 10K and PU 5K to confirm the packer is set. 9/18/2017 9/18/2017 1.00 COMPZN RPCOMP RURD P RU pressure testing equipment. Fill 8,206.0 8,206.0 21:30 22:30 the IA with 8.5 ppg seawater 3%KCL and allow the air to migrate out. 9/18/2017 9/18/2017 0.25 COMPZN RPCOMP PRTS P PT the IA to 2500 psi for 10 minutes 8,206.0 8,206.0 22:30 22:45 (good test). 9/18/2017 9/18/2017 0.25 COMPZN RPCOMP PRTS P Attempt to pressure up and shear the 8,206.0 8,206.0 22:45 23:00 ball seat but unable to build pressure. Ball seat might have shear while setting the packer or the ball came off seat and would not re-seat. 9/18/2017 9/18/2017 0.25 COMPZN RPCOMP PACK P PU to 175K to shear the PBR and 8,206.0 8,173.0 23:00 23:15 continue to PU to 8173'MD to pull the cup assembly from the PBR. 9/18/2017 9/18/2017 0.25 COMPZN RPCOMP RURD P Lay down the joint of DP,DP pup and 8,173.0 8,173.0 23:15 23:30 crossover. Change elevators to 4-1/2" tubing. 9/18/2017 9/19/2017 0.50 COMPZN RPCOMP PULD P POOH with packer setting tool laying 8,173.0 7,926.0 23:30 00:00 down 4-1/2"tubing from 8173'to 7926' MD at midnight. Page 12/16 Report Printed: 9/26/2017 • • 0 0Operations Summary (with Timelog Depths) 1J-120 Conoco"hittips Rig: DOYON 14 Job: RECOMPLETION Time Log >s' Start Depth Start Time'. End Time Dur(hr) Phase Op Code Activity Code Time P T-X Operation (ftKB) End.Depth(ftKE) 9/19/2017 9/19/2017 9.25 COMPZN RPCOMP PULD T Continue to POOH with packer setting 7,926.0 34.0 00:00 09:15 tool laying down 4-1/2"tubing from 7926'to 34'MD. 9/19/2017 9/19/2017 0.25 COMPZN RPCOMP BHAH T Lay down packer setting tool. 34.0 0.0 09:15 09:30 9/19/2017 9/19/2017 1.00 COMPZN RPCOMP BHAH T Clean and clear the floor. 0.0 0.0 09:30 10:30 9/19/2017 9/19/2017 1.00 COMPZN RPCOMP RURD T PJSM. Hang Tec wire sheave and 0.0 0.0 10:30 11:30 pull ESP cable over the wind wall sheave to the rig floor. 9/19/2017 9/19/2017 0.50 COMPZN RPCOMP SFTY T PJSM with rig crew,Centrilift and 0.0 0.0 11:30 12:00 Access on running and installing the ESP completion. 9/19/2017 9/19/2017 1.00 COMPZN RPCOMP PUTB T PU,MU and RIH with ESP completion 0.0 191.0 12:00 13:00 to 191'MD. 9/19/2017 9/19/2017 5.00 COMPZN RPCOMP ALFT T Motor lead was bad. Splice a new 191.0 191.0 13:00 18:00 motor lead to the ESP cable. SimOps: general housekeeping. 9/19/2017 9/19/2017 0.75 COMPZN RPCOMP ALFT T Connect motor lead to the annular 191.0 191.0 18:00 18:45 connection port. 9/19/2017 9/19/2017 0.50 COMPZN RPCOMP PUTB T Continue to RIH with ESP completion 191.0 401.0 18:45 19:15 per tally to 401'MD. 9/19/2017 9/19/2017 0.50 COMPZN 'RPCOMP ALFT T Install SureSENS gauge with Tec wire 401.0 401.0 19:15 19:45 to the gauge mandrel. PT gauge (good test). 9/19/2017 9/19/2017 0.25 COMPZN RPCOMP PUTB T Continue to RIH with ESP completion 401.0 512.0 19:45 20:00 per tally to 512'MD. 9/19/2017 9/19/2017 0.75 COMPZN RPCOMP ALFT T PJSM. Mobilize slickline tools to the 512.0 512.0 20:00 20:45 rig floor. 9/19/2017 9/19/2017 0.50 COMPZN RPCOMP ALFT T RU HES slickline. 512.0 512.0 20:45 21:15 9/19/2017 9/19/2017 0.75 COMPZN RPCOMP ALFT T MU 3.83"OD centralizer with 3.80" 512.0 512.0 21:15 22:00 OD drift below. RIH but tagged up at 54'SLM. Worked the drift down to 61' SLM,POOH,inspected the drift and found new scratch marks on the 3.80" OD drift. RD slickline. 9/19/2017 9/19/2017 0.75 COMPZN RPCOMP ALFT T Lay down a joint of 4-1/2"R3 tubing 512.0 470.0 22:00 22:45 and lay down the GLM. MU and RIH with new GLM to 470'MD 9/19/2017 9/19/2017 0.50 COMPZN RPCOMP ALFT T RU slickline and MU 3.83"OD 470.0 470.0 22:45 23:15 centralizer with 3.80"OD drift below. Drift down to the no-go sub at 336', POOH and lay down the drift assembly. 9/19/2017 9/20/2017 0.75 COMPZN RPCOMP ALFT T PU the 4-1/2"R3 tubing joint with the 470.0 470.0 23:15 00:00 motor/seal assembly inside. Pull the motor/seal assembly from the joint of tubing. Service the seal section. 9/20/2017 9/20/2017 0.50 COMPZN RPCOMP ALFT T RIH with motor/seal assembly,engage 470.0 470.0 00:00 00:30 wet connect,test(good test),release running tool and POOH. 9/20/2017 9/20/2017 1.00 COMPZN RPCOMP ALFT T PU and MU pump assembly. RIH, 470.0 470.0 00:30 01:30 install the pump assembly and POOH. 9/20/2017 9/20/2017 0.75 COMPZN RPCOMP ALFT T PU and MU pack off assembly. RIH, 470.0 470.0 01:30 02:15 set pack off and POOH. • Page 13/16 Report Printed: 9/26/2017 • • Operations Summary (with Timelog Depths) 1J-120 ConocoPhiiiips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code .:Activity Code Time P-T-X : Operation (ftKB) End Depth(ftKB) 9/20/2017 9/20/2017 0.75 COMPZN RPCOMP PRTS T Fill the pipe with seawater and RU' 470.0 470.0 02:15 03:00 pressure testing equipment. PT the pack off to 2000 psi for 10 minutes (good test). RD pressure testing equipment. 9/20/2017 9/20/2017 0.50 COMPZN RPCOMP ALFT T PU,MU and RIH with tubing stop. Set 470.0 470.0 03:00 03:30 the tubing stop on top of the pack off and POOH. RD slickline. 9/20/2017 9/20/2017 1.75 COMPZN RPCOMP PUTB T Continue to RIH with ESP completion 470.0 1,472.0 03:30 05:15 on 4-1/2"R3 tubing spooling ESP cable/Tec wire and installing cannon clamps from 470'to 1472'MD. 9/20/2017 9/20/2017 0.75 COMPZN RPCOMP ALFT T Perform electrical checks on the ESP 1,472.0 1,472.0 05:15 06:00 cable and Tec wire(good test on both). RU slickline,MU 3.83"OD centralizer with 3.80"OD drift below, RIH to 1000'and POOH. 9/20/2017 9/20/2017 0.25 COMPZN RPCOMP SFTY T PJSM with new rig crew,Access, 1,472.0 1,472.0 06:00 06:15 Centrilift and HES slickline. 9/20/2017 9/20/2017 0.25 COMPZN RPCOMP ALFT T RD slickline. 1,472.0 1,472.0 06:15 06:30 9/20/2017 9/20/2017 1.50 COMPZN RPCOMP PUTB T Continue to RIH with ESP completion 1,472.0 2,475.0 06:30 08:00 on 4-1/2"R3 tubing spooling ESP cable/Tec wire and installing cannon clamps from 1472'to 2475'MD. 9/20/2017 9/20/2017 1.00 COMPZN RPCOMP ALFT T Perform electrical checks on the ESP 2,475.0 2,475.0 08:00 09:00 cable and Tec wire(good test on both). RU slickline,MU 3.83"OD centralizer with 3.80"OD drift below, RIH to 1000',POOH and RD slickline. 9/20/2017 9/20/2017 1.50 COMPZN RPCOMP PUTB T Continue to RIH with ESP completion 2,475.0 3,436.0 09:00 10:30 on 4-1/2"R3 tubing spooling ESP cable/Tec wire and installing cannon clamps from 2475'to 3436'MD. 9/20/2017 9/20/2017 0.50 COMPZN RPCOMP ALFT T -Perform electrical checks on the ESP 3,436.0 3,436.0 10:30 11:00 cable and Tec wire(good test on both). RU slickline,MU 3.83"OD centralizer with 3.80"OD drift below, RIH to 1000',POOH and RD slickline. 9/20/2017 9/20/2017 2.00 COMPZN RPCOMP PUTB T Continue to RIH with ESP completion 3,436.0 4,549.0 11:00 13:00 on 4-1/2"R3 tubing spooling ESP cable/Tec wire and installing cannon clamps from 3436'to 4549'MD. 9/20/2017 9/20/2017 0.50 COMPZN RPCOMP ALFT T Perform electrical checks on the ESP 4,549.0 4,549.0 13:00 13:30 cable and Tec wire(good test on both). RU slickline,MU 3.83"OD centralizer with 3.80"OD drift below, RIH to 1200',POOH and RD slickline. 9/20/2017 9/20/2017 1.50 COMPZN RPCOMP PUTB T Continue to RIH with ESP completion 4,549.0 5,550.0 13:30 15:00 on 4-1/2"R3 tubing spooling ESP cable/Tec wire and installing cannon clamps from 4549'to 5550'MD. Page 14/16 Report Printed: 9/26/2017 e • r • Operations Summary (with Timelog Depths) 1J-120 Caincicontillips Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr)I', Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 9/20/2017 9/20/2017 0.50 COMPZN RPCOMP ALFT T Perform electrical checks on the ESP 5,550.0 5,550.0 15:00 15:30 cable and Tec wire(good test on both). RU slickline,MU 3.83"OD centralizer with 3.80"OD drift below, RIH to 1000',POOH and RD slickline. 9/20/2017 9/20/2017 1.50 COMPZN RPCOMP PUTB T Continue to RIH with ESP completion 5,550.0 6,465.0 15:30 17:00 on 4-1/2"R3 tubing spooling ESP cable/Tec wire and installing cannon clamps from 5550'to 6465'MD. 9/20/2017 9/20/2017 0.50 COMPZN RPCOMP ALFT T Perform electrical checks on the ESP 6,465.0 6,465.0 17:00 17:30 cable and Tec wire(good test on both). RU slickline, MU 3.83"OD centralizer with 3.80"OD drift below, RIH to 1000',POOH and RD slickline. 9/20/2017 9/20/2017 1.50 COMPZN RPCOMP PUTB T Continue to RIH with ESP completion 6,465.0 7,426.0 17:30 19:00 on 4-1/2"R3 tubing spooling ESP cable/Tec wire and installing cannon clamps from 6465'to 7426'MD. 9/20/2017 9/20/2017 0.50 COMPZN RPCOMP ALFT T Perform electrical checks on the ESP 7,426.0 7,426.0 19:00 19:30 cable and Tec wire(good test on both). RU slickline, MU 3.83"OD centralizer with 3.80"OD drift below, RIH to 1000',POOH and RD slickline. 9/20/2017 9/20/2017 1.75 COMPZN RPCOMP PUTB T Continue to RIH with ESP completion 7,426.0 8,159.0 19:30 21:15 on 4-1/2"R3 tubing spooling ESP cable/Tec wire and installing cannon clamps from 7426'to 8142'MD. Engage the seal assembly into the PBR and locate out at 8159'MD with 5K down(PU=115K and SO=75K). 9/20/2017 9/20/2017 0.25 COMPZN RPCOMP HOSO P Lay down 2 joints and MU 3.73'space 8,159.0 8,090.0 21:15 21:30 out pup joint. 9/20/2017 9/20/2017 0.75 COMPZN RPCOMP THGR P PU the landing joint and PU the tubing 8,090.0 8,120.0 21:30 22:15 hanger. MU the landing joint to the tubing hanger and MU the tubing hanger to the completion string. Lower the tubing hanger to a good working height at the rig floor. 9/20/2017 9/21/2017 1.75 COMPZN RPCOMP ALFT P Centrilift MU the ESP cable splice to 8,120.0 8,120.0 22:15 00:00 the tubing hanger. SimOps: Pump 280 bbls of 8.6 ppg corrosion inhibited seawater with 3% KCL down the IA. 9/21/2017 9/21/2017 1.50 COMPZN RPCOMP ALFT P Continue to MU the ESP cable splice 8,120.0 8,120.0 00:00 01:30 to the tubing hanger. SimOps: Pump 280 bbls of 8.6 ppg corrosion inhibited seawater with 3% KCL down the IA. 9/21/2017 9/21/2017 1.75 COMPZN RPCOMP ALFT P Cut the Tec wire,feed through the 8,120.0 8,120.0 01:30 03:15 tubing hanger and MU the splice. Perform electrical checks on the ESP cable and Tec wire(good test on both). 196 cannon clamps installed. Page 15/16 Report Printed: 9/26/2017 • • Operations Summary (with Timelog Depths) 1J-120 ConocoPhiflips AS.xka Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code. Activity Code Time P-T-X Operation MKS) End Depth(ftKB) 9/21/2017 9/21/2017 1.50 COMPZN RPCOMP THGR P Land the tubing hanger and 4 LSD. 8,120.0 8,157.0 03:15 04:45 PT the lower and upper seal to 250/5000 psi for 5 minutes. Run in the remaining LDS and pull the landing joint. SimOps: DHD shot a fluid level at 1250'MD. RU HES slickline.MU 3.83"OD centralizer with 3.80"OD drift below, RIH to 1000',POOH and RD slickline. 9/21/2017 9/21/2017 0.25 COMPZN WHDBOP MPSP P PU and MU the dry rod. Install the 4" 0.0 0.0 04:45 05:00 H BPV and lay down the dry rod. 9/21/2017 9/21/2017 0.25 COMPZN WHDBOP OTHR P Lower the ESP cable over the sheave 0.0 0.0 05:00 05:15 to the spooling unit. 9/21/2017 9/21/2017 2.25 COMPZN WHDBOP NUND P Pull the riser and mouse hole. ND the 0.0 0.0 05:15 07:30 BOP stack,set back on the stump and secure for transport. 9/21/2017 9/21/2017 2.00 COMPZN WHDBOP NUND P Test and terminate ESP cable/Tec 0.0 0.0 07:30 09:30 wire through the tubing head adapter. 9/21/2017 9/21/2017 3.00 COMPZN WHDBOP NUND P NU the tubing head adapter and NU 0.0 0.0 09:30 12:30 the tree. PT the tubing hanger void to 250/5000 psi(good test). 9/21/2017 9/21/2017 0.25 COMPZN WHDBOP PRTS P PT the tree to 250/5000 psi(good test 0.0 0.0 12:30 12:45 no visual leaks). 9/21/2017 9/21/2017 2.25 COMPZN WHDBOP MPSP P Drain fluid from double valve and pull 0.0 0.0 12:45 15:00 HP BPV dart-had fluid movement below BPV,RU Lubricator and pull BPV 9/21/2017 9/21/2017 2.00 COMPZN WHDBOP FRZP P RU LRS to the top of the tree. PT the 0.0 0.0 15:00 17:00 lines to 3000 psi. Pump 55 bbls down the tubing at 4 BPM(ICP=200 psi and FCP=700 psi). RD from the tree and RU to the IA. PT the lines to 2000 psi. Pump 74 bbls down the IA at 4 BPM=55 psi. RD LRS. SimOps: Prep to skid the rig floor into moving position. 9/21/2017 9/21/2017 1.00 COMPZN WHDBOP MPSP P RU the lubricator,Install 4"H BPV and 0.0 0.0 17:00 18:00 RD the lubricator. 9/21/2017 9/21/2017 1.00 DEMOB MOVE RURD P Secure and dress the tree. Clean up 0.0 0.0 18:00 19:00 the cellar are. *Release Doyon 14 at 19:00 hours on 9-21-17` Page 16/16 Report Printed: 9/26/2017 KUPOD • 1J-120 ConocoPhillips ^ Well Attrib Max Angle&MD TD Alaska,Inc, Wellbore API/UWI Field Name Wellbore Status ncl(`) MD(ftKB) Act Btm(ftKB) Conoc0Phillips 500292335200 WEST SAK PROD 92.84 13,392.03 15,822.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1J-120,10/16/20178--.17.07 AM SSSV:NONE 100 12/12/2015 Last WO: 9/21/2017 32.29 6/16/2007 Vertical achemanc(actual) _ Annotation Depth(ftKB) End Date Annotation 'Last Mod By End Date Last Tag: REV REASON:GLV C/O-SET 2000#SOV© pproven 10/12/2017 Hanger;22.4 3652'RKB Casing Strings 113.e Wfitt"""""""abbalu aubLu.gnu 4 4..A.Mt,Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TOG)... Wt/Len(I...Grade Top Thread CONDUCTOR 20 19.124 30.0 108.0 108.0 94.00 K-55 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 103/4 9.950 30.3 4,100.0 2,469.6 45.50 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread -Ati CONDUCTOR;30.0-108.04..".." "-"-^^^INTERMEDIATE _ 7 5/8 6.875 27.4 9,944.4 3,871.2 29.70 L80 BTCM _.. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(NO)... Wt/Len g...Grade Top Thread GAS LIFT.3,6524at D LINER LEM 41/2 3.958 8,164.5 8,398.0 3,636.6 12.60 L-80 IBTM Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl C) Item Des Corn (in) SURFACE;30.3-4,100.0 8,164.5 3,582.0 75.48 SLEEVE 5.75"ID Tie back sleeve 5.750 -• 8,175.4 3,584.8 75.37 PACKER 5.5"x7.625""HRD"ZXP Liner Top Packer w/hold 4.960 GAS LIFT;7,685.6 Or down slips . 8,183.2 3,586.7 75.30 SBE 190-47 Casing Seal Bore Recepetacle 6.30"OD x 4.750 Gauge;7,753.7 4.75"ID ■ 8,202.8 3,591.8 75.11 XO BUSHING 5.5"BTC x 4.5"IBT Cross Over Bushing 3.960 Siding Sleeve-CMO;7,8226 �I 8,213.8 3,594.6 75.13 NIPPLE DB Nipple 3.75"ID,4.5"IBTM Box x Pin 3.750 8,225.1 3,597.5 75.40 HANGER LEM Above Hook Hanger 3.970 in Sliding Sleeve-CMU;7,853.6 1 8,235.7 3,600.1 75.66 HANGER LEM Below Hook Hanger 3.930 XO Enlarging(Tubing);7,914 5IR Motor Shroud/Centralizer\ 8,394.7 3,635.9 77.45 SEAL ASSY 190-47 Non-Locating Seal Assembly 3.880 7.917 6\ Annular Connection Port; - Casing Description (in) ) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(1...Grade Top Thread 7,953.8 ar D LINER HH 1 OD 4 1/21ID(in3.4761 8,235.11 8,515.71 3,659.31 11.601 L-80 BTC Promo Sob:7,9921 ii Liner Details aR No-Go 3.80"Sub;8,013.2 {- Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl C) Item Des Com (in) ill 8,235.1 3,600.0 75.65 HANGER Baker Model B-1 Hook Hanger 7 5/8"x 4 1/2"(Inside 5.600 Sliding Sleeve-CMU,8,066.2 I csg) 8,252.0 3,604.1 76.06 HANGER Baker Model B-1 Hook Hanger 7 5/8"x 4 4.000 1/2"(Outside csg) Lecabor,8,133.3 8,418.7 3,641.0 77.96 ECP Baker Payzone External Casing Seal Assembly;;e,133 1 = Y Packer 3.960 POR,8.134.0 1= 8,484.8 3,653.9 79.62 BENT JT 4 1/2",12.6 ppf,L-80 STL BENT joint Blank Casing 3.992 PACKER:8,147.0 _ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread LOCATOR,8,162.6 B LINER LEM 4 1/2 3.958 8,369.7 8,815.5 3,705.4 12.60 L80 IBT Liner Details MULE SHOE;8,163.5 Nominal ID Xi Top(ftKB) Top(TVD)(ftKB) Top Incl C) Item Des Corn (in) - - 8,369.7 3,630.4 77.42 PACKER ZXP 5-1/2"x 7-5/8" Liner Top Packer TOP 5.530 8,388.4 3,634.5 77.45 SBR 109-47 Casing Seal Bore Receptacle 626"OD x 4.750 4.75 • • 8,407.4 3,638.6 77.67 XO BUSHING XO Bushing 5-1/2"Hydril 563 x 4-1/2"IBT 4.500 •• 8,663.9 3,682.1' 81.60 HANGER LEM Above Hook Hanger 3.688 8,670.7 3,683.1 81.62 HANGER LEM Inside Hook Hanger 3.688 8,737.6 3,693.1 81.09 NIPPLE Camco"DB-6"Nipple,I.D.3.562",IBT 3.562 8,770.0 3,698.2 80.75 BENT JT 4-1/2,12.6 ppf.L-80,X/O Bent Jt.IBT Box X STL 3.958 8,812.2 3,704,9 81.17 SEAL ASSY Baker Seal Assembly 4-1/2"STL Box up 3.880 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread D LINER LEM;8,164.5-8,398.0 B LINER HH 4 1/2 3.476 8,670.4 8,955.3 3,725.1 11.60 L-80 BTC IIII Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl C) Item Des Corn (in) 8,670.4 3,683.1 81.62 HANGER Baker Model B-1 Hook Hanger 7 5/8"x 4 1/2"(Inside 5.600 csg) D LINER HH,0,235.1-es15.7 8,687.2 3,685.5 81.62 HANGER Baker Model B-1 Hook Hanger 7 5/8"x 4 4.000 1/2"(Outside csg) r. t 8,857.2 3,711.5 81.86 ECP Baker Payzone External Casing Packer 3.960 8,924.9 3,720.9 82.04 BENT JT -4 1/2",12.6 ppf,L-80 STL BENT joint Blank Casing 3.992 • ' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I.,.Grade Tap Thread A LINER Slotted 4 1/2 3.476 8,771.7 15,200.0 3,935.7 11.60 L80 BTC w/TR Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl C) Item Des Corn (in) 8,771.7 3,698.5 80.73 PACKER 5.5"x 7.63"Baker"HRD"ZXP Liner Top Pkr 5.750 II.i 8,790.7 3,701.5 80.84 NIPPLE "RS"Packoff Seal Nipple,6.07"OD/4.87"ID 4.870 B LINER LEM,8,3657-6,815.5 8,793.6 3,702.0 80.89 HANGER 5.5"X 7.63""Flex-Lock"Liner Hgr,6.59"OD/4.85 4.850 ar 8,803.4 3,703.5 81.04 SBE 190-47 Seal Bore Ext,6.29"OD/4.75"ID 4.750 15,113.5 3,935.4 90.39 Swell Packer Swell Packer#2 3.960 • 15,174.8 3,935.4 89.54 Swell Packer Swell Packer#1 3.960 Tubing Strings B LINER HH,86704-8,955.3 ' TubingDescription String Ma...ID(in) TopftKB Set Depth(ft..Set Depth ND ) (ftKB) p ( 1(...Wt(Ib/ft) Grade Top Connection Tubing RWO 2017 41/2 3.958 22.3 8,145.5 3,577.3 12.60 L-80 IBTM Completion Details INTERMEDIATE,27.4-9,944.4 Top(ftKB) Top(ND)(ftKB) Top Incl C) Item Des Corn Nominal ID (in) -� SLOTS,10,2400-12.205.0 22.3 22.3 0.00 Hanger Tubing Hanger,Vetco-Gray MB222A offset 10 3/4 x 4 1/2 3.900 w/false bowl SLOTS;12,506.0-13,1450 7,753.8 3,478.3 74.60 Gauge Baker SureSENS Gauge 3.938 7,822.6 3,496.6 74.59 Sliding Sleeve Gas Venting Sliding Sleeve CMD,3.875"X Profile, 3.900 -CMD Access(Closed) SLOTS;13,445.0.14,179.0 7,853.6 3,504.8 74.79 Sliding Sleeve Gas Venting Sliding Sleeve CMU,3.875"X Profile, 3.900 -CMU Access(Open) SLOTS;14,350.0-15,113.01_7 7,917.6 3,521.3 75.31 Motor Motor Shroud/Centralizer,Access,5-1/2"FJL Pin x 5- 4.900 Shroud/Genu 1/2"FJL Pin alizer A LINER Slotted;8,7771.- 15,200.0, KUP #0D • 1J-120 ConocoPhillips III Alaska,Int:. CoracoPhilNps i.Yi. Annotation End Date 1J-120,10/16/2017 8 1798 AM Last WO: 10/5/2017 Vence!schematic(actual) 9L2V 20,17 Hanger;22,4 u. Completion Details ..,.,,,,e...e..uuru.e......�.......u, ...�...a w. Nominal ID Top(ftKB) Top(TVD)(ftKB) Top not Cl Item Des Com (in) 7,953.8 3,530.4 75.54 Annular Annular Connection Port,Access,5-1/2"FJL Box x 4-1/2" 3.840 Connection Vam Top Box Port -A-.-CONDUCTOR;30.0-108.04•4,*`/N�� 7,992.4 3,540.0 75.77 Profile Sub B-Profile Sub,Access,4-1/2",12.6#,L-80,TXP Box x 3.956 Box GAS LIFT;3,652.4 8,013.2 3,545.1 75.89 No-Go 3.80" No-Go 3.80"Sub,Access,4-1/2,12.68,L-80,TXP Box x 3.800 Sub Pin 8,068.2 3,558.4 75.94 Sliding Sleeve CMU Sliding Sleeve,3.813"DB profile,Baker(Open) 3.810 SURFACE;30.3-4,100.0 - -CMU 8,132.3 3,574.0 75.78 Locator Locater Sub,Baker,GBH-22(bottom of the locator 3.880 GAS LIFT,7,685.6 spaced out 1.59') 8,133.1 3,574.2 75.78 Seal Baker 192-47 Seal Assembly 4-1/2",12,6#,L-80,IBTM 3.870 Gauge;7,753.7 Assembly Box Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..)Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection Stacker Packer RWO 4.51 3.980 8,134.0 8,199.3 3,590.9 12.60 L-80 IBTM Sliding Sleeve-CMD;7,822.6 2017 Completion Details Sliding Sleeve-CMU;7,853.6 Nominal ID XO Enlarging(Tubing),7,914 5 Top(ftKB) Top(TVD)(ftKB) Top Incl C) Item Des Com (in) Motor Shroud/Centrar er: 8,134.0 3,574.5 75.77 PBR PBR,Baker,80-47 with 6.69"scoop guide,4-1/2"12.68 4.750 7.91761 TC-II Pin down Annular Connection Port; 2663.8 lir 8,147.0 3,577.7 75.64 PACKER 'Premier Packer,Baker,659-387,4-1/2",12.6#TC-ll Box 3.870 Mfi Profile Sub;7,9924 Si z Pin No-Go 3.80"Sub;0,013.2 ! 8,162.6 3,581.6 75.49 LOCATOR Locater(bottom of the locator spaced out 1') 3.980 1. 8,163.51 3,581.8 75.49(MULE SHOE Mule Shoe Joint 3.980 Sliding Sleeve-CMU;8,068.2 Perforations&Slots Shot Den Locator:8,132.3 _ Top(TVD) Btm(TVD) (shots/ Seal AssemPBblyR;88,,133134.0 ft) Type_ Top(COB) Btm(ROB) (ftKB) (ftKB) Zone Date Type Com; i. � 10,240.0 12,205.0 3,873.8 3,905.2 WS A2,1J- 5/17/2007 32.0 SLOTS 2.5"x.125",4 PACKER,8,147.0 ■ II 120 circumferencial rows/ft 3" iii LOCATOR;6162.6 centers staggered 18 deg !ir9 12,506.0 13,145.0 3,911.2 3,930.0 WS A2,1J- 5/17/2007 32.0 SLOTS 2.5"x.125",4 MULE SHOE;8,163.5 ICI 120 circumferential rows/ft 3" s centers staggered 18 deg _ 13445.0 14,179.0 3,920.6 3,922.9 WS A2,1J- 5/17/2007 32.0 SLOTS 2.5"x.125",4 I 120 nft 3" centerscircumferestaggeredtialrows/18 deg 14,350.0 15,113.0 3,925.6 3,935.5 WS A2,1J- 5/17/2007 32.0 SLOTS 2.5"x.125",4 120 circumferencial rows/ft 3" centers staggered 18 deg Mandrel Inserts MI- St D LINER LEM',8.164.5-8,398.0 all onN ® Top(ND) Valve Latch Port Size TRO Run ® Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1 3,652.4 2,307.1 Camco KBG-2 1 ESP SOV BK 1.000 0.0 9/27/2017 2000 2 7,685.6 3,460.3 Camco KBG-2 1 ESP DMY BK-5 0.000 0.0 9/21/2017 'P Notes:General&Safety D LINER HO;8,235.1-8.5157 • End Date Annotation 6/16/2007 NOTE: MULTI-LATERAL WELL-1J-120(A-SAND),1J-120L1(B-SAND),1J-120L2(D-SAND) •I , 7/23/2008 NOTE VIEW SCHEMATIC w/9.0REV 1/6/2014 NOTE:WORKOVER-2014 9/21/2017 NOTE:WO FI:III B LINER LEM,8,369.7-8,815.5 B LINER HH',8,670.4-8,955.3 ' INTERMEDIATE;27.4-9,944.4 SLOTS,10,240.0-12,205.0 SLOTS;12.506.0-13.145.0 SLOTS;13,4450-14,179.0 SLOTS,14,350.0-15,113.01 A LINER Slotted;8,771.7- 15,200.0� • • • k'Ruirio Regg, James B (DOA) ` O LP From: Rig 14 <rig14@doyondrilling.com> Sent: Tuesday, September 12, 2017 7:21 AM <7a IZZ�` To: Regg,James B (DOA) lqt l Subject: Rig 14 BOP test Attachments: 9-9-17 BOP test 1J-120 Revision.xlsx; BOPE-Rolling test to unseat hanger.docx; BOPE TEST SEQUENCE.docx; BOP test 9-10-17 CHART 1.pdf; BOP test 9-10-17 CHART 2.pdf; BOP test 9-10-17 CHART 3.pdf; BOP test 9-10-17 CHART 4.pdf; BOP test 9-10-17 CHART 5.pdf Hi Jim, We have revised the Bop test report form and included the test sequence.The SOP is here along with the scanned test charts. I installed sticky notes for each test that I hope will answer any question you may have.The scanned charts are a little hard to see unless zoomed in, I also hope this does not create a problem. Thanks, Axel From: Doyon 14 Company Man [mailto:doyonl4cm@conocophillips.com] Sent: Monday, September 11, 2017 9:23 AM To: Rig 14 Cc: Kneale, Michael L(SolstenXP) Subject: FW: [EXTERNAL]RE: Doyon 14 BOP test SCANNED 7ER 2"E9f Thanks, Larry Hill/ Bob Finkbiner Doyon 14 Rig Supervisors 907-670-6125 From: Regg,James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Monday, September 11, 2017 9:21 AM To: Doyon 14 Company Man <doyonl4cm@conocophillips.com> Cc:Jones,Jeffery B (DOA)<jeff.jones@alaska.gov> Subject: [EXTERNAL]RE: Doyon 14 BOP test Send us your rolling test procedure. We also require that you provide the test charts for the rolling test plus the charts for the normal BOPE test—make sure the test charts are CLEARLY annotated. Document all test failures on a single test report(Form 10-424). Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. 1 • • • STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report ottiA11 *AII BOPE reports are due to the agency within 5 days of testing* Submit to:jim.reqqalaska.qov;AOGCC.Inspectorse.alaska.gov; phoebe.brooks a(�,alaska.gov Contractor: Doyon - Rig No.: 14 DATE: 9/9/17 Rig Rep.: Hansen/Tower Rig Phone: 670-6126 Operator: CPAI Op. Phone: 670-6125 Rep.: Hill/Finkbiner E-Mail rig14@doyondrilling.com Well Name: KRU 1J-120 PTD# 2070450 - Sundry# )4, Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Test Pressure(psi): Rams: 250-2500 ' Annular: 250-2500 , Valves: 250-2500 - MASP: 629 ' MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen. P - Well Sign P - Upper Kelly 1 - P - Housekeeping P Rig P - Lower Kelly 1 - P - PTD On Location P - Hazard Sec. P _ Ball Type 2 - P - Standing Order Posted P - Misc. NA Inside BOP 1 P - FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 . 13-5/8 - P ' Pit Level Indicators P P #1 Rams 1 - 2-7/8 x 5 - P - Flow Indicator P P #2 Rams 1 - Blinds - FP ✓ Meth Gas Detector P P #3 Rams 1 - 2-7/8 x 5 - P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln.Valves 1 • 3-1/8 - P - Inside Reel valves 0 NA HCR Valves 2 - 3-1/8 . P Kill Line Valves 2 - 3-1/8 FP ✓ Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure(psi) 2950 P . CHOKE MANIFOLD: Pressure After Closure(psi) 1550 . P Quantity Test Result 200 psi Attained (sec) 38 P No.Valves 14 P - Full Pressure Attained(sec) 196 . P _ Manual Chokes 1 • P - Blind Switch Covers: All stations Yes - Hydraulic Chokes 1 P ' Nitgn. Bottles#&psi(Avg.): 6 @ 2016 psi - P - CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 2 • Test Time: 14.8 - Hours Repair or replacement of equipment will be made within days. Notify the AOGCC of repairs with written confirmation to:AOGCC.Inspectors@alaska.gov Remarks: Test Annular, Upper&Lower VBR's(4 1/2"test jt).Test one 4"HT-38 FOSV, one 4-1/2"EUE FOSV&one 4" HT-38 Dart valve.Tests performed against hanger&blanking plug. Blinds&kill manual failed. Changed out&tested good. Test#7-sensor on test manifold failed, replaced w/good sensor. Conducted rolling test on untested components to 250/2500psi. Pull hanger, M/U &land test plug.Test blinds, choke&kill manuals,4"TIW; J. Jones witness rolling test. AOGCC Inspection 24 hr Notice Yes Date/Time 9/7/17,3:08am Waived By Jeff Jones / Test Start Date/Time: 9/9/2017 0600am ' (date) (time) Witness - Test Finish Date/Time: 9/10/2017 1700pm ems-& kpp,/7'VCS O P-)1/LA — 2 Sa— Form 10-424(Revised 03/2017) 2017-0909_BOP_DoyonI4_KRU_1J-120 • • Doyon 14 BOPE Test 1J-120 9-10-17 PRE-TEST Body Test - Test #1 Lower Rams - Test #2 Upper Rams, Choke Valves 1,12,13,14 & 2" secondary kill valve _ Test #3 Upper rams, Kill HCR &Choke HCR (slight ht bleed off pp ( 9 ) RE-TEST Test #3 Upper rams, Kill HCR &Choke HCR (Good Test) - Test #4 Upper rams, Manual Kill & Manual Choke (Failed High Test) RE-TEST Test #4 Upper rams, Manual Kill & Manual Choke (Failed High Test ) - Trouble shoot offline-Suspect Manual Kill leaking Test #5 Annular, Choke Valves 9,11 Test #6 Blinds, Choke Valves 5,8,10,Upper IBOP Test #7 Blinds, Choke Valves 4,6,7 & Lower IBOP NOTE: Trouble shoot and found flat pressure sensor RE-TEST Test #7 Blinds, Choke Valves 4,6,7 & Lower IBOP Test #8 Blinds, Choke Valve #2 and 4" HT-38 Dart Valve (Failed High Test) - RE-Test #8 Blinds, Choke Valve #2 and 4" HT-38 Dart Valve Failed High Test -Again Suspect Test Dart or Hanger leaking or possibly Blind Rams. No viewable leaks indicating #2 choke valve or 4" Ht-38 Dart Valve Leaking. Well on a Vacuum and no way to verify fluid from annulus Perform Two Trouble Shooting Test, Lower Rams against hanger both test failed. Lower rams Showing No Viewable leaks. Suspect Test Dart or Hanger leaking Trouble Shoot Test again, Lower Rams against hanger and it Began holding pressure Attempt Test #8 again offline and failed Test Decision made to change out test dart, Blinds and Manual Choke valve. Test#9 4-1/2" IBT FOSV (Test Completed While Changing out Blinds and Manual Choke valve) Test #10 4" HT-38 FOSV Test #11 Blinds, Choke Valve #2,4" HT-38 Dart Valve, Manual Kill (Failed High Suspect Hanger leaking) Perform Two Trouble Shooting Test, Lower Rams against hanger, Lower rams Showing No Viewable leaks Suspect Test Dart or Hanger leaking • • Doyon 14 BOPE Test 1J-120 9-10-17 Test #12 Choke Valve #2, 4" HT-38 Dart Valve Note: Continued to test BOPE while contacting AOGCC to request pulling Hanger and make up test plug ✓ to string so testing could be completed without further issue Sec e4 Ls 4-u Test #13 Choke Valve #3 "314pctrV r hurt c s �,o't 7 Test #14 Super Choke Test #15 Hydraulic & Manual choke on choke manifold Test #16 Rolling Test on Blind Rams, Choke Valve 2,4,6 and Kill HCR valve No viewable leaks on surface equipment Test #17 Rolling test on Upper pipe rams, Manual kill and Manual choke valves No viewable leaks on surface equipment Test #18 Blind rams, Choke valves 4,6,7 &Kill HCR -- NOTE: Test witnessed by AOGCC Rep. Jeff Jones Test #19 Upper Pipe Rams Manual Kill & Manual Choke NOTE: Test witnessed by AOGCC Rep. Jeff Jones • • )o,,n, 14 3e PE s i ( it',;.i .....i 6:.5 iolji"lr,, .0,,,,,, ,,,,,. °•n..„........iss, .....4.1 ";. I 0,OOP•,..W.•:=AM,.'"vil`. 2".* I.-:::P.4."1 kik? ,,E11:0010, 10•1.1.o.s.vigirsnal=4.41 44,imiamb ...4t, , ".001.'' ;100001.00.0.,0041:7,441h. 404.446,1404: //r/ rit0011. 0000•15°41,14 4.1*.."1.1 .** ,4N*• 4 e / to r%()0 ere,Vw,0 i Ws.liz.:..wmr•a Nem a r=4,marl.mailillf_alt p4b..44 W..S 1/44V.4:1/4,,,R,s- 1,,lozo / ,, "°.°°asV.Wift,- ...* .` ..N N. '‘11/41* ‘1\\ fr Eli '-- 00111:,44 % \ \.. ....... i if" - •,°11Mall \‘‘.w. % ilitt#4 �ofrsok 006"Wark* ‘ \ 'a\\:\ �, ..._ .., . . . �� \\�110 V4E0 4\‘ c1/4 % 11N I 1%. ili,, �� ��, . ..: P y' . ,.:1111111 � ,..1111� � , � q ,. 11l 11 �i . • . . 111�, �lj 1Q,1 111 ��, .., .�G� VA'Aiblillfiliiiiii,1111 . 1� ` 111 .fit+ r �,tt / ,�rr�, � _ 1�`�� 1 Illi 1 ,� SII 1�lII 111111 �,. �jaIII � � a .� � II �� � t � � III � � r � . ' � � ij� tt�� N� 111 �� � �I�l� �������� 111����rtgie, .�. ,i' '1/ �j111 f�1 h �1 �,,1 1. ` 4Air, I N111'11141 ;#44/0/74li �fittitINVqvat• Itime ,.. ei � , ‘sc, ....... ..... ,4 / i i .%%le % �� .....��� .,moi / ,% y/4ei q'i �� fir. �.��a�lso-% // / t �� e� ♦ i - hice . /' � �tip• ` � � �� � / �' .�� oma � � . /,r va-4,4,_4e#Aga ��"�fro;),‘"• / / � ��».,�. ..w 7's�`� '�'`ice-� rk°, ����/•�° S Summary 1 .p df Comments on BOP test 9-10-17 CHART 1 . df Page: 1 Number:1 Author:rig14 Subject:Sticky Note Date:9/11/2017 8:39:41 PM Test#7 Choke Valves 4,6,7&Lower IBOP NOTE:Trouble shoot and found flat pressure sensor Number:2 Author:rig14 Subject:Sticky Note Date:9/11/2017 6:29:43 PM PRE-TEST Body Test Number:3 Author:rig14 Subject:Sticky Note Date:9/11/2017 6:26:10 PM Test#6 Blind Rams,Choke Valves 5,8,10,Upper IBOP Number:4 Author:rig14 Subject:Sticky Note Date:9/11/2017 6:30:40 PM Test#1 Lower Rams Number:5 Author:rig14 Subject:Sticky Note Date:9/11/2017 6:45:12 PM Test#5 Annular,Choke Valves 9,11 Number:6 Author:rig14 Subject:Sticky Note Date:9/12/2017 6:41:46 AM Test#2 Upper Rams,Choke Valves 1,12,13,14&2"secondary kill line demco valve Number:7 Author:rig14 Subject:Sticky Note Date:9/12/2017 6:42:11 AM Test#3 Upper rams,Kill HCR&Choke HCR Number:8 Author:rig14 Subject:Sticky Note Date:9/12/2017 6:43:04 AM RE-TEST Test#4 Manual Kill&Manual Choke Failed High Test Trouble shoot offline-Manual Kill leaking Number:9 Author:rig14 Subject:Sticky Note Date:9/11/2017 8:38:51 PM Test#4 Upper rams,Manual Kill&Manual Choke Failed High Test Number:10 Author:rig14 Subject:Sticky Note Date:9/11/2017 8:24:09 PM RETEST Test#3 Upper rams,Kill HCR&Choke HCR I 01(641 (4 ft d -e-.i 0 E.W laF 0 10*4:ftftf..7.**:" a Pitr="--"=4::::41W*447 ' 4, w-0 .°1 *"42,...0"."-=Ma--1/215 .*•• k•••,.,.4s,s,.- N • •XfrP1.0,....".,....00 .....-,-u'r"mi.sw71-1=0,........ 4...,, '•::NM 439: \ // Op „0„....-0•Wii- ---.1"....tft-...NN,‘4,0 s- N /. 0 0 . ,„ .,,,..„,,mir......,, ,..v.,z....,,,,._„ 0. 1114,, . \ d 19 OP &.10000.6. 2M1.1.0/..:Z11,4*A‘0, , ‘ ittiAAt / /; .° ro0OMMaimmikeill 7%* f t °°°0:10=1:44.141.:44* NN X% \ i • 00.°000.40=r1ark.V \ \\\* --a-zo \ 4 4, / ,e 1,...Si, .vo,\\\ \ \ A% lt� �� itittoitiat. „ ,. ,. ,, ���e X1111111; Oritiertteta, ile owe: o'it % % lal% �� �iw �. �..� � * �...�� �..�`�� »>1111�iii •,,,•; � •�,v....��r�'1 1111111111111Ng r �J 11 �� �,,, 1111`1Ir � 111 •��' ......�r���11i� r� ri � 111II i� rr ��� ��� II1�� 1i'� fi ::: m 1111 �'�� �1I 11 Af ` �II 11 ilip .., �i� ` II �� II `III 118gal% �=,, 11��I ���M� 11111 1l►t��� . .�: 1 1 ��11111/1/ �zo ,,:4. 5,,1444,„ ii X 11 1����kill �� riptitifiiil 111 v�� � . . ..��� SAS// l0„„,.. im i, Attliclz,A ,‘,‘ . * t,....-nots ei/- , / 01/ 1111114 %Ili \ vook•EraPti '/ /,fril// ?// / fill a,,c, 474 448 1 I gal0 \\V \ \\\ � . /'7 , /// ///**Sal0moi/o..0 14(. � .,44.107.SAT i 0 I Pr. 1 / \ N 4% _, •-. ____,. .7.m r -- j,, ,.s„,p' P:.-,4 7------1-”-:m- 7 1''-'-'-%-- ' / N, .*... ..,.........mmi . ___, ,-,--, ,_ ___ .....„,_-_---- , ,,, , _ i +'r._ mo ,._ `_-_. L _ _ �, • I Summary of Comments on BOP test 9-10-17 CHART 2.pdf Page: 1 Number:1 Author:rig14 Subject:Sticky Note Date:9/11/2017 8:21:11 PM Test#8 Blinds,Choke Valve#2 and 4"HT-38 Dart Valve Failed High Test Number:2 Author:rig14 Subject:Sticky Note Date:9/11/2017 8:20:56 PM RE-Test#8 Blinds,Choke Valve#2 and 4"HT-38 Dart Valve Failed High Test-Again Suspect Test Dart or Hanger leaking or possibly Blind Rams(no viewable leaks indicating#2 choke valve or 4"Ht-38 Dart Valve Leaking Well on a Vacuum and no way to verify fluid from annulus Pulled Test Dart and run new test dart Number:3 Author:rig14 Subject:Sticky Note Date:9/11/2017 8:21:19 PM RE-TEST Test#7 Blinds,Choke Valves 4,6,7&Lower IBOP Number:4 Author:rig14 Subject:Sticky Note Date:9/11/2017 8:14:01 PM Perform Two Trouble Shooting Test,Lower Rams against hanger Lower rams Showing No Viewable leaks Suspect Test Dart or Hanger leaking Number:5 Author:rig14 Subject:Sticky Note Date:9/11/2017 7:13:19 PM Trouble Shooting Test,Lower Rams against hanger Began holding pressure • • Noai14 I3uPc- T -00-;': 0.-=' •,-=-,-:.?"-W..... -<_- ,,, .,001,10'imTheirlET4W-.4"%`"4 .4ft.1:- 7/0.4' 'NW -----,:=2.1 -.9 ,,... ,.ftwi- ' / Os. ,Forpow.-T=2,. ,...*:*,, ,,*,.. /I' OroSfle5,:_„,001.01 -41. 7` 's,,.\.\\ .:11/, z \tor 40,031 r„,,,,,e_t _- ....____ . .......4s, 4„,_**,a,s>,... .. \-\ 'doe 04 4,--"Voirov,.......-7Wav 7,,,tr,„1„, . \ . /II /A 4 III *14r0sG,.=.�:,.+,ea v�� V\ ilkil ♦ � ,/ I ♦�► ,• _..� ♦trivf/t �i � // /�� � � �� � ��// ` ,/ / i . . __�., ♦ ♦� \\\ �, / � t4//4, ... c _... �. �� \\ 7 lilt ''' �'��'�I, �jig0. �ugit�►�����`o``�```viii �i, •.,.. 4,Nitatilli ,. ,00 �`���x \x\11111 )11111111. r � 1, • . .. �.s. 1101 11 a . �. �. 1,.��� 1111 �,� „,b,,,� �,�� 11 • 1ill IIIII 111 r��� �� ri � � � � .�� �� , p 111 �� ��jai ile «� tt4� . ## �1 ��� �IIiJi!iiiij hirilli I , tki it�litt� 4 . y , 4 1 lb ' vtitont*,\;:sn. . millittolos • y / - ' -4-vohtiti- Q_, . .. ...... 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NN„ 111; 2'0 _-____-6.-_-_- f--___, /.,., 0,,vy ,,,,,,,A -t‘--_= -._-,---.:_ ,--- .2-----_-_:. _------:- ------ -,-.,- ,, , __,,,,o, ..„-,,-_ „ _. 41w _-. _ = = -____- _::---- • I Summary of Comments on BOP test 9-10-17 CHART 3.pdf Page: 1 Number:1 Author:rig14 Subject:Sticky Note Date:9/12/2017 6:46:51 AM Test#11 Blinds,Choke Valve#2,4"HT-38 Dart Valve,Manual Kill Failed High Suspect Hanger leaking,No visible surface equipment leaks Number:2 Author:rig14 Subject:Sticky Note Date:9/11/2017 9:04:53 PM Test#10 4"HT-38 FOSV Number:3 Author:rig14 Subject:Sticky Note Date:9/11/2017 9:14:05 PM Perform Two Trouble Shooting Test,Lower Rams against hanger Lower rams Showing No Viewable leaks Suspect Test Dart or Hanger leaking Number:4 Author:rig14 Subject:Sticky Note Date:9/11/2017 9:19:51 PM Test#12 Choke Valve#2,4"HT-38 Dart Valve Note:Continued to test BOPE while contacting AOGCC to request pulling Hanger and make up test plug to string so testing could be completed without further issue Number:5 Author:rig14 Subject:Sticky Note Date:9/11/2017 9:21:07 PM Test#13 Choke Valve#3 Number:6 Author:rig14 Subject:Sticky Note Date:9/11/2017 9:21:44 PM Test#14 Super Choke Number:7 Author:rig14 Subject:Sticky Note Date:9/11/2017 9:03:08 PM Test#9 4-1/2"IBT FOSV Test Completed While Changing out Blinds and Manual Choke valve Number:8 Author:rig14 Subject:Sticky Note Date:9/11/2017 9:23:26 PM Test#15 ADJ Manual choke on choke manifold iti ILA/4 4 if ' 11 WI.°1 "."' - 0//°;••••• •,0:111.' i' mw AU'ree`..& Aft. .*'------: •,0".°•!...., .. ,`"."`".4 ---ift.--44116F -----, itib//// ; 1 .°°.I. m I l'°°..11°. vg r.....rr•°W1..A.'Wm m"..w=a. a•.m1S "°"w4°.ua.*w ' 4*.ft '' ' thaildiaiher / WassCer...W.* *,.. .,ft%%b,.# N rib takkggild cfr"a°0011.,..46\\*\ ,,, Ill 1111111111111110r; / ;/4/ - pre 4k4::ii ilf;frItIN, 1% IIIIIHIffl ((( '4:21.t.. * 1116is tivtrssiis 111 Il il I I I I I illelliellett 4411174:k 44 Al‘ " \ Itt\S"t, A "Low Ittittitiatillailligisti III ,1% s. .• 5i tvr , \., ,,,..., i • S Summary of Comments on BOP test 9-10-17 CHART 4.pdf Page: 1 Number:1 Author:rig14 Subject:Sticky Note Date:9/12/2017 6:48:45 AM Test#17 Rolling test on Upper pipe rams,Manual kill and Manual choke valves No visible leaks on surface equipment Number:2 Author:rig14 Subject:Sticky Note Date:9/12/2017 6:48:09 AM Test#16 Rolling Test on Blind Rams,Choke Valve 2,4,6 and Kill HCR valve No visible leaks on surface equipment -1-3ek- 4s.auud ^ ; „ , . .„ .°1',,,, ..--01-6-f-_____- 4:___ ______ z , ,„,... ... ...., - -..... .- .-.: _-,7,- """".....: /, 4'.o.o.PlaMOr ' '. .1:***-l''f*? ' / I/f*/ ,/ ,%°rn.°4..:=-21=='*‘:m:41 .'4 4”ft" ''4`W**1'43/4 N%. .itia ; ' 0 0 a•-W M.riami*O`.ill 44 4.4''•'%' \' .,, 0 0'11 .6"ft7\.4. 'N\k‘,‘ -‘,4 :Ole ralt. ' 1\ ‘k \\\ I7 ,vi • / /ht Mg* i/ / .0 • '13111*: \ '' , \\Ag ''`i) %\% \ \ ''11111111rOlet*V *; OW t it 111111 1111111011114,14„terf:014%* Ussl\f\ '\ ktwomiliatitigr **31'14°11114141 ‘ milk tr,,,k, trail: %.,, Aoiontilitrett, %pi ,., .\ Itivtkuv‘ k, %,-,. .I.A:.4441414041,00011111111110- \\ , .• VAAV V ‘v:ii, v tint /,:i 'VI /#41/14#100/414411111 ', \V\ • °I?", *,\ 4.4ft, le '0 \\\‘‘.\\.\\. , - '\ #4101056441/ irStApii / ‘,..„:.".4,..imairta0� ,-41. • • Summary of Comments on BOP test 9-10-17 CHART 5.pdf Page: 1 Number:1 Author:rig14 Subject:Sticky Note Date:9/11/2017 9:26:48 PM Test#19 Upper Pipe Rams Manual Kill&Manual Choke NOTE:Test witnessed by AOGCC Rep. Jeff Jones Number:2 Author:rig14 Subject:Sticky Note Date:9/11/2017 9:26:42 PM Test#18 Blind rams,Choke valves 4,6,7&Kill HCR NOTE:Test witnessed by AOGCC Rep. Jeff Jones • gtnit1 • Document Type: Document No. Page No. Standard Operating Procedure TBD 1 of 7 Department: Rev.Date Rev.No. F Operations Document Title: DOYON DRILLING, INC. BOPE-Rolling test to unseat hanger BOPE-Rolling test to unseat hanger (Rig 14) 1.0 PURPOSE The purpose of this procedure is to: • Ensure the integrity of the blowout preventer equipment(BOPE). • Establish specific tasks, roles and responsibilities, and training requirements that will minimize risk to personnel and rig equipment. 2.0 SCOPE This procedure applies to DDI Rig 14. 3.0 PERSONAL PROTECTIVE EQUIPMENT (PPE) • Hard hat • Safety glasses • Steel toe boots • Hearing protection • Gloves 4.0 TOOLS • Test manifold • Test hose • Test pump • Test plug • Test joint • Martin Decker chart and hose • High Pressure warning signs • Crescent and pipe wrench • Tape measure • 5' stick • Chalk • Test x-o for the saver sub. 5.0 WASTES • N/A Doyon Drilling Inc. PAPER COPIES ARE UNCONTROLLED. The controlled version of this document resides on the DDI web site. • • Title: BOPE-Rolling test to unseat hanger Rev# Page 2 of 7 Department: Operations Document No.: TBD 6.0 DEFINITIONS / ACRONYMS Term Definition BOP, BOPE Blowout preventer; blowout preventer equipment HCR High Closing Ratio IBOP Inside blowout preventer LDS Lockdown screws 7.0 REFERENCES/DOCUMENTS • SOP-252, Wellbore Fluid Monitoring. • SOP-1045, RIG14_Operating Remote BOP Station for Stack and Surface Diverter • SOP-717, RIG 14_Accumulator Draw Down Test • BP/Doyon well control bridging document. • Accumulator worksheet WARNINGS: Ensure all pressure is bled off before opening rams or valves. 8.0 ROLES AND RESPONSIBILITIES Role Responsibilities Toolpusher 1. Ensure all DDI policies and procedures are understood and followed. 2. Ensure there are at least two barriers of isolation (i.e., kill weight fluid, casing cemented and tested, storm packer, two way check, etc.). 3. Check requirements on the permit to drill and well program. 4. Ensure AOGCC inspector has been notified and permission has been granted to conduct rolling test before proceeding. Driller 1. Assign competent personnel to perform work. 2. Ensure that a pre job safety meeting and hazard assessment is conducted before work begins. 3. Ensure all workers are properly trained in the use of equipment. 4. Have another qualified employee verbally and visually witness which BOP equipment will be functioned. 5. BOP equipment will be functioned from the remote panel located in the doghouse. If the remote panel in doghouse cannot be used, STOP and contact the toolpusher and agree on a method to function the BOPs from the accumulator station. 6. Ensure a new hazard assessment is completed if the job scope changes. Doyon Drilling Inc. PAPER COPIES ARE UNCONTROLLED. The controlled version of this document resides on the DDI web site. • Title: BOPE-Rolling test to unseat hanger Rev# Page 3 of 7 Department: Operations Document No.: TBD Role Responsibilities kap 7. Ensure all necessary lockdown screws(LDS)are backed out and packing nuts are tight. 8. Determine which spool test plug will be installed. 9. Keep the annulus valve below the test plug open throughout test, upper plug upper annulus; lower plug lower annulus. 10. Always ensure pressure is bled to 0 psi after each successful test. 11. Ensure annulus is kept full and well bore fluid volumes are monitored during testing per SOP-252, Wellbore Fluid Monitoring. 12. Check requirements on the permit to drill and well program. 13. Ensure there are at least two barriers of isolation(i.e.,kill weight fluid, casing cemented and tested, storm packer,two way check, etc.). 14. The order of the tests should be conducted in the same order as the tests written in the SOP. Deviations from the procedure are to be stated on the test report. Workers 1. Display High Pressure signs. NOTE: Keep personnel out of the cellar area while the test is in progress unless they are instructed to enter the area.Pressure should be bled off. 2. Ensure all necessary LDS are backed out and packing nuts are tight. 3. Grease the choke manifold prior to the test. 4. Ensure all tools and equipment are maintained and in safe working order. 5. Review appropriate procedures/SOP pertaining to the operation. Pit Watcher 1. Monitor well bore fluids per DDI SOP-252, Wellbore Fluid Monitoring. 9.0 PROCEDURE 1. Conduct a PJSM and hazard assessment. ALL tests- 10 minutes low and 10 minutes high. 2. Rig up and pressure test Perform Rolling test against all BOPE components that was unable to obtain a flat line against a leaking hanger. 3. This may include up to Choke valve#1,Annular,Upper Pipe rams,Blind Rams,Lower Rams, Manual Choke,Kill Manual, Kill HCR, Choke HCR all other components can be tested without having to test against the hanger. 4. Line up to test necessary components which may vary depending on untested components listed above using this SOP or refer to the Doyon Rig 14 BOPE testing SOP-691 for proper valve line ups or a write a Hazardous recognition work sheet if necessary. Doyon Drilling Inc. PAPER COPIES ARE UNCONTROLLED. The controlled version of this document resides on the DDI web site. • • • Title: BOPE-Rolling test to unseat hanger Rev# Page 4 of 7 Department: Operations Document No.: TBD Rolling Pressure test as follows: Bring pressure up to 250 psi with test pump on the Chart.Maintain 250 psi with test pump if pressure declines. Maintain pressure for 10 minutes while looking for any ROPE leaks at Surface. r-- Pressure test to State required pressure with test pump on the Chart keeping pressure above the ✓ required pressure psi for 10 minutes while checking for any BOPE leaks. 10.0 EXAMPLE TESTS Test# Test Description Test 1 1. CLOSE annular/choke valves 1, 12, 13, 14 and HCR kill. OPEN valve 22 and mud manifold bleeder. • NOTE: All tests will be low 250/high 3500, OR as required by the State, up to 5,000 psi Rolling Pressure test as follows: 1. Bring pressure up to 250 psi with test pump on the Chart.Maintain 250 psi with test pump if pressure declines. Maintain pressure for 10 minutes while looking for any BOPE leaks at Surface. 2. Pressure test to State required pressure with test pump on the Chart keeping pressure above the required pressure psi for 10 minutes while checking for any BOPE leaks. NOTE: Visually look for leaks at the Annular,above#1 choke valve and the mud manifold bleed for this test. 3. Bleed All presure to zero Test 2 CLOSE Upper pipe rams, manual kill, choke HCR. OPEN Annular, kill HCR,#1 choke valve Rolling Pressure test as follows: 1. Bring pressure up to 250 psi with test pump on the Chart. Maintain 250 psi with test pump if pressure declines. Maintain pressure for 10 minutes while looking for any BOPE leaks at Surface. 2. Pressure test to State required pressure with test pump on the Chart keeping pressure above the required pressure psi for 10 minutes while checking for any BOPE leaks. NOTE: Visually look for leaks at the Upper rams ,above#1 choke valve and the mud manifold bleed for this test. Doyon Drilling Inc. PAPER COPIES ARE UNCONTROLLED.The controlled version of this document resides on the DDI web site. • • • Title: BOPE-Rolling test to unseat hanger Rev# Page 5 of 7 Department: Operations Document No.: TBD Test# Test Description 3. Bleed All presure to zero Test 3 1. CLOSE Lower pipe Rams Rolling Pressure test as follows: 1. Bring pressure up to 250 psi with test pump on the Chart. Maintain 250 psi with test pump if pressure declines. Maintain pressure for 10 minutes while looking for any BOPE leaks at Surface. 2. Pressure test to State required pressure with test pump on the Chart keeping pressure above the required pressure psi for 10 minutes while checking for any BOPE leaks. NOTE: Visually look for leaks at the Lower rams for this test. Bleed All presure to zero Open lower pipe rams and lay down test joint. Test 4 1. CLOSE Blinds,Manual Choke Open Choke HCR Rolling Pressure test as follows: 1. Bring pressure up to 250 psi with test pump on the Chart. Maintain 250 psi with test pump if pressure declines. Maintain pressure for 10 minutes while looking for any BOPE leaks at Surface. 2. Pressure test to State required pressure with test pump on the Chart keeping pressure above the required pressure psi for 10 minutes while checking for any BOPE leaks. NOTE: Look for leaks at blind rams and above#1 choke valve Doyon Drilling Inc. PAPER COPIES ARE UNCONTROLLED. The controlled version of this document resides on the DDI web site. • Title: BOPE-Rolling test to unseat hanger Rev# Page 6 of 7 Department: Operations Document No.: TBD Motion Pressure A Biological Eliminate + Radiation Control Protect Heat/Cold Electrical Gravity oe�� yo Energy Source Identification and Analysis Protective Measures Energy Source Involved Eliminate Energy Control Energy Protective Barriers Source Source (Guard, PPE, etc.) 1. Motion Use safe hand and Use proper PPE. body placement • Hammers Use tailing line. • Tugger • Loads 2. Chemical Review MSDS. Use proper PPE. • Mud • Diesel • Glycol 3. Radiation 4. Electrical Ensure all covers are Use proper PPE. in place and in good • Switches condition while operating switches. 5. Gravity Use safe hand and Use proper PPE. body placement. • Ladder • Choke manifold 6. Heat/Cold Doyon Drilling Inc. PAPER COPIES ARE UNCONTROLLED. The controlled version of this document resides on the DDI web site. • S Title: BOPE-Rolling test to unseat hanger Rev# Page 7 of 7 Department: Operations Document No.: TBD Protective Measures Energy Source Involved Eliminate Energy Control Energy Protective Barriers Source Source (Guard, PPE, etc.) 7. Biological 8. Pressure Stay clear. Use proper PPE. Post warning signs. • Tests Doyon Drilling Inc. PAPER COPIES ARE UNCONTROLLED.The controlled version of this document resides on the DDI web site. • • • Regg, James B (DOA) From: Jones, Jeffery B (DOA) Sent: Sunday, September 10, 2017 3:14 PMS 9'11 (17 To: Doyon 14 Company Man Cc: Regg,James B (DOA) Subject: Re: Doyon 14 BOP test Bob & Larry, Your proposed plan forward is approved provided you perform a "rolling test" to required test pressure on all untested BOPE components&ensure there are no external leaks prior to pulling the hanger. I will come out to your location & witness the procedure. Thanks, Jeff Jones AOGCC 744-4446 Sent from my iPhone On Sep 10, 2017, at 6:55 AM, Doyon 14 Company Man <doyon14cm@conocophillips.com>wrote: Good Morning Jeff, Bob sent the e mail below this morning,just checking to make sure you received it. Thanks, Larry Hill/Bob Finkbiner Doyon 14 Rig Supervisors 907-670-6125 From: Doyon 14 Company Man Sent:Sunday, September 10, 2017 3:54 AM To: 'jeff.jonesPalaska.gov' <jeff.jones@alaska.gov> Subject: Doyon 14 BOP test Jeff We have located the x-o's to hang the completion string on the test plug and have gotten the OK from Vetco Gray to conduct a final pressure test to 2500 psi on the blind rams and manual kill and choke lines. I would like to pull and lay down the hanger and joint below it. Make up the test plug to the tubing, set it and test. All other components have been tested. Thanks, Larry Hill/ Bob Finkbiner Doyon 14 Rig Supervisors 907-670-6125 1 • • Regg, James B (DOA) From: Jones, Jeffery B (DOA) Sent: Sunday, September 10, 2017 7:34 AM r C, gull To: Doyon 14 Company Man 1 l Cc: Regg,James B (DOA) Subject: RE: Doyon 14 BOP test Bob & Larry, If the Vetco test dart fix we discussed on the phone doesn't work,you have approval to proceed provided you first perform a "rolling test" to 2500 psi on BOPE test components that have not been successfully tested; Blinds, LPR's etc., verifying there are no external leaks prior to executing the plan you have proposed. Jeff B.Jones Petroleum Inspector Alaska Oil &Gas Conservation Commission N. Slope Ofc: 907-659-2714 Mobile: 907-744-4446 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jeff B. Jones at 907-659-2714 or jeff.jones@alaska.gov. From: Doyon 14 Company Man [mailto:doyonl4cm@conocophillips.com] Sent: Sunday, September 10, 2017 6:55 AM To:Jones,Jeffery B (DOA) <jeff.jones@alaska.gov> Subject: FW: Doyon 14 BOP test Good Morning Jeff, Bob sent the e mail below this morning,just checking to make sure you received it. Thanks, Larry Hill/ Bob Finkbiner Doyon 14 Rig Supervisors 907-670-6125 From: Doyon 14 Company Man Sent: Sunday, September 10, 2017 3:54 AM 1 • • To: 'jeff.jones@alaska.gov' <jeff.jones@alaska.gov> Subject: Doyon 14 BOP test Jeff We have located the x-o's to hang the completion string on the test plug and have gotten the OK from Vetco Gray to conduct a final pressure test to 2500 psi on the blind rams and manual kill and choke lines. I would like to pull and lay down the hanger and joint below it. Make up the test plug to the tubing, set it and test.All other components have been tested. Thanks, Larry Hill/ Bob Finkbiner Doyon 14 Rig Supervisors 907-670-6125 2 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim ReggI J c /I DATE: 9/12/17 P. I. Supervisor 1 FROM: Jeff Jones SUBJECT: BOPE Test Petroleum Inspector KRU 1J-120 a-r Ci `r_ l Conoco-Phillips Alaska Inc SCAN PTD PTD 2070450 September 9, 2017: I was contacted by Doyon Rig #14 Rig Manager, Mr. Axel Hansen, who informed me he had been testing for 8 hours and was having difficulty completing a successful BOPE test prior to performing a tubing swap well workover - operation on CPAI's well 1J-120 in the Kuparuk River Field (KRF). Mr. Hansen and I spoke at length regarding the problems he was having achieving the required passing BOPE pressure tests and his efforts to troubleshoot the cause(s). He said he had performed several successful tests when something changed and he was unable to get a passing test on any subsequent equipment tests. The charted pressure bleed off appeared to be the same no matter how or what equipment was lined up to test. I suggested he continue to troubleshoot the problem and eliminate all possible avenues of leakage, including his test equipment, and let me know the outcome. ' September 10, 2017: At 0215 hours a.m. I was contacted by CPAI company representative Mr. Bob Finkbiner, who informed me that they had eliminated every possible avenue of leakage and were certain that they had no visible leakage anywhere in the BOPE equipment. He believed that plugged tubing hanger penetrations or seals were leaking down hole and he requested he be allowed to remove the tubing hanger and 2 joints of 4.5" tubing, cross over the tubing to the test plug and re-land the tubing in the well head on the test plug and attempt to complete a successful BOPE test. Because they were using a Vetco-Gray tubing blanking plug and test dart to facilitate the tests, I requested that they install a new test dart to make sure that wasn't the issue. I told him that he must clean the BOPE for inspection, the well must be static and a - "rolling pressure test" showing no external leakage anywhere in the BOPE system would be required to permitted pressure (2500 PSI), prior to removing the tubing hanger. Mr. Finkbiner indicated it would take several hours to acquire the threaded crossovers needed for this operation and I told him I would come out to witness this operation as soon as I was able to re-schedule tests planned for that day. On arrival at the location, Mr. Hansen and I reviewed the charts of all the previous tests and determined that it would be necessary to do the rolling test on the blinds and the manual kill and choke valves on the BOPE stack. I inspected the cleaned BOPE stack and associated equipment while the required 2500 PSI was held on the blind rams and 2017-0910_BOP_Doyonl4_Rolling-Test_KRU_1 J-120_jj.docx Page 1 of 2 • the manual choke and kill valves on the BOPE stack with the test pump. No leakage was noted on any of the BOPE. The well was monitored and was static. I then allowed the tubing hanger to be removed and replaced with the test plug and re- v landed. Photo of the tubing hanger: 5 ` 1 f vI � , p x $ .r . " . , . . f { ' ' gin - f ' ' , ‘, ..t(k, { +� op :- I - :1,.-- 'A.:::4:':'''''4-''r '''''' -t-irdh 1' ' ''''' ' :'I:I -177.7:704— 4'.1 s ' 0fZE5 M w. The testing resumed and the BOPE tests of the blinds, choke and kill manual valves and a 4-inch FSV were successfully completed without failure. I inspected the tubing hanger and noted no significant damage to the external seals. One of the two plugged hanger penetrations had an 8-inch (approximate) nipple extending from the bottom of the hanger that appeared to be damaged, probably when the hanger was installed in 2014. When this nipple was removed it contained water, which may indicate it was leaking during BOPE testing. Summary: I witnessed a rolling partial BOPE test procedure that was required prior to replacing the tubing hanger with a test plug and the successful completion of a BOPE test on Doyon Rig #14, performing a tubing swap workover operation on CPAI's KRF well 1J-120. Attachments: none 2017-0910_BOP_Doyon 14Rolling-TestKRU_1 J-120_j j.docx Page 2 of 2 -' Iti • Cr: 41, 1 WrW o � � rr o v CO N 3 0o❑ _0 o C7 N Z• W N L 'Q O +, h -.1.....•CO. 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They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. p~Q ~-~~~ Well History File Identifier Organizing caone~ RE CAN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: BY: Maria Project Proofing BY: Maria Scanning Preparation BY: Maria ^ Rescan Needed III IIIIII I) II (IIIII DIG TAL DATA Diskettes, No. ` ^ Other, No/Type: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: Date: Date: p Other:: /s/ IIIIIIIIIIIIN IIIII ~ ,S, ~p Production Scanning • r i / i 3 x 30 = ~ + ~3 = TOTAL PAGES ~ ~ ~ (Count does not include cover sheet) Date: ~S~ III IIIIIIIII~ IIIII Stage 1 Page Count from Scanned File: ~,~ (Count does include cover sheet) Page Count Matches Number in Scanning Pre aration: _~ YES NO BY: Maria Date: ~ ~q ~S~ ~ ~ ~ ~/ ~ ! Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: Scanning is complete at this point unless rescanning is required. /s/ III II~III IIII) I) II ReScanned BY: Maria Comments about this file: Date: Quality Checked ~s~ II'I II'll II'I II) 10/6/2005 Well History File Cover Page.doc .:, a _ \* . m ~ x ~I.. ~~.. ~,~«. s ~w -: ti~~ MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Gas Lift Survey: 1J-120 Run Date: 4/19/2010 C~ April 29, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1J-120 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-23352-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael. b arreto @hal lib urton. com Date: r ~~~ ~ 5 1 ~ Cc r'~ --~ .~ , , _ ~, Signed: "~ ;~~~~ ~~ ';' =' ~ ~' ~~ ~ _. a;_ -~ ~~~ DATA SUBMITTAL COMPLIANCE REPORT 6/22/2009 Permit to Drill 2070450 Well Name/No. KUPARUK RIV U WSAK 1J-120 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23352-00-00 MD 15822 ND 3952 Completion Date 6/16/2007 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIREO INFORMATION Mud Log No Sampies No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR/Res (data taken from Logs Portion of Master Wel~ Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / i y e meairrmc numoer Name acaie mea~a no srart ~top ~n rcecervea commen[.s D D Asc Directional Survey 28 15822 Open 8/2/2007 pt 15342 LIS Verification 4073 15822 Open 8/23/2007 LIS Veri, GR, FET, ROP D C Tap 15342~nduction/Resistivity 4073 15822 Open 8/23/2007 LIS Veri, GR, FET, ROP og Production 5 Blu 1500 8797 Case 11/14/2008 PPL w/Deft and Ghost, GR, CCL, STP, Gradio 27- Oct-2008 D C Pds 17177/f'roduction 1500 8797 Case 11/14/2008 PPL w/Deft and Ghost, GR, CCL, STP, Gradio 27- ' Oct-2008 ' og See Notes 2 Blu 100 4000 Case 5/15I2009 GLS, Pres, Temp, Gradio, I Spin 8-May-2009 ED C Pds 18022 See Notes 100 4000 Case 5/15/2009 GLS, Pres, Temp, Gradio, Spin 8-May-2009 I ~D C 18130'~See Notes 0 0 Open 6/10/2009 EWR logs in PDS, EMF and CGM graphics og Induction/Resistivity 25 Col 108 15822 Open 6/10/2009 MD ROP, EWR, DGR og Induction/Resistivity 25 Col 108 3951 Open 6/10/2009 ND EWR, DGR Well Cores/Samples Information: Sample lnterval Set Name Start Stop Sent Received Number Comments ~ ~ DATA SUBMITTAL COMPLIANCE REPORT 6/22/2009 Permit to Drill 2070450 Well Name/No. KUPARUK RIV U WSAK 1J-120 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23352-00-00 MD 15822 ND 3952 Completion Date 6/16/2007 Completion Status 1-OIL Current Status 1-OIL UIC N ADDITIONAL IPFORMATIQN 1 / ( vl„a, Well Cored? Y~ i Daily History Received? y~' '" Chips Received? .-~f-P1-- Formation Tops ~N Analysis ~~L!-#~ Received? Comments: Compliance Reviewed By: _ Date: ~ S~~~ ~"~ ~ • ~ ~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1J-120+L1+L1PB1+L1PB2+L1PB3+L1PB4+L2+L2PB1 AK-MW-5005556 ~ June l, 2009 The technical data listed below is being submitted herewith. Please address any problems or concems to the attention of: Bryan Burinda, Sperry Drilling, Arctic Blvd., Anchorage, AK 99518 1J-120+L1+L1PB1+L1PB2+L1PB3+L1PB4+L2+L2PB1 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 50-029-233 52-00,60,71,72,73,61,74 2" x 5" TVD RESISTIVITY & GAMMA R.AY Logs: 50-029-23352-00,60,61 Digital Log Images 50-029-233 52-00,60,71,72,73,61,74 L1PB1, L1PB2, L1PB3, L1PB4 and L2PB1 have no TVD. 1 Color Log 1 Color Log 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNiNG AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda ~o~ _~ c~~ /,~O~d ~~ ~ -~~ 6900 Arctic Blvd. ~'j-~-p~j(~ !~ (3/ ~~ ~~~ Anchorage, Alaska 99518 ~ ~ / ~ ~ Office: 907-273-3536 ~ `~ ~33 Fax: 907-273-3535 B , n.com l ~~ ~~ i ~ ~~C~ J~l~ ~ 0 20G9 Date: ~as~~ ~il ~ Gas C~r-§. Gorr~ni~sicn An~h~~~ae / Signed: 05/12/09 ~ ~~~~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~ ~ ~~ ~ ~~,~ ~1 AY ~. 5 ~ ~OG9 al~~ka C~6! ~ ~as ~~~. ~or~r~e~~~~~ ~~ch~ra~~ NO. 5228 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD ~ Log Description 3A-18 AYS4-00069 PERF/SBHP SURVEY - 6 04/26/09 1 1 3C-OS 614B-00033 GLS $"~ ( 04/21/09 1 1 2M-25 B146-00034 GRlTEMP LOG /9 /- 04/22/09 1 1 1 R-19A AYS400065 SBHP SURVEY -r C `~ 3~ 04/23/09 1 1 3G-13 AYS400067 SBHP SURVEY -( 04/2M09 1 1 3G-05 AYS4-00066 SBHP SURVEY 04/24/09 1 1 3F-07 B14B-00038 SBHP SURVEY - ~ OM24/09 1 1 3F-08 B14B-00037 SBHP SURVEY 04/2M09 1 1 3M-25A B14B-00040 SBHP SURVEY 04/25/09 1 1 3K-08 614B-00039 SBHP SURVEY C( 04/25/09 1 1 2N-318A AWJI-00026 MEM BHP SURVEY -Q 04/27/09 1 1 2Z-07 B146-00045 SBFlP SURVEY . L OM29/09 1 1 2Z-01A 6146-00044 SBHP SURVEY ~-_ 04/29/09 1 1 3K-102 ANHY-00080 GLS 04/30/09 1 1 2W-06 B04C-00036 PRODUCTION PROFILE 05/02/09 1 1 2W-12 B04C-00037 PRODUCTION PROFILE - p 05/03/09 1 1 3C-02 604C-00045 POWERCUTTER W/SBHP SURVEY 05/09/09 1 1 1 J-120 604C-00043 GLS S 0 O 05/08/09 1 1 31-11 B04C-00044 SMALL TBG PUNCH W/SBHP 05/08/09 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. ~~~ ~ ~~ ~ ~ aC~ ~ a{ y'~~ i! ;?i ~~~~~~~~~~r~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description ~ N0. 4957 Company: Alaska Oil & Gas Co~s Gomm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Date BL Kuparuk Color CD 11/10/08 1 C-119 11978488 INJECTION PROFILE ~ 10/16/OS 1 1 1J-101 11978491 PRODUCTION PROFILE 10/19/OS 1 1 3H-02 12080447 INJECTION PROFILE ~ -~- ~- 10/24/08 1 1 3K-24 1t978500 SBHP 10/26/08 1 1 1J-120 11978501 PRODUCTION PROFILE 10/27/08 1 1 3H-24 12080454 INJECTION PROFILE 10/28/08 1 1 3S-15 11978491 SBHP SURVEY - 10/18/OS 1 1 iH-OS 12100434 INJECTION PROFILE - ~ 10/30/08 1 1 1 H-09 12096560 INJECTION PROFILE ~~ ~,C ~0~3 ~~ ~~} ('~-~ 10/30/08 1 1 Please sign and return one copy of this transmitta~ to Beth at the above address nr fax to (907) 561-8317. Thank you. • ~ ~C~~9~~~ STATE OF ALASKA o C j `~ Q ZOO~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA~~~~ ~~~ ~~~s. ~~rnr~~~sior~ 1. Operations Pertormed: Abandon ^ Repair Well ~' Plug Perforations ~ Stimulate ~ ~Y ~' ~~~~ Alter Casing ^ Pull Tubing Q' Pertorate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter S uspended Weil ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, IIIC. Development ^~ ' Exploratory ~ 207-045 /• 3. Address: Stratigraphic ^ Service ^ 6. AP! Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-23352-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 109' • 1 J-120 ' 8. Properry Designation: 10. Field/Pool(s): ADL 25661,~25650 ~ Kuparuk River Field / West Sak Oii Pool • 11. Present Well Condition Summary: Total Depth measured 15822' • feet true vertical 3952' • feet Plugs (measured) Effective Depth measured 15200' feet Junk (measured) true vertical 3935' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 20" 108' 108' SURFACE 4072' 10.75" 4100' 2470' INTERMEDIATE 9917' 7.625" 9945' 3872' A LINER SLOTTE 6428' 4.5" 15200' 3935' Perforation depth: Measured depth: ~o2ao'-12205', 12505'-13144', 13445'-14179', 14350'-15133' true vertical depth: 3s7a'-3908', 3911'-3929', 3921'-3924', 3926'-3936' Tubing (size, grade, and measured depth) 4.5", L-80, 8178' MD. Packers & SSSV (type & measured depth) Baker HRD ZXP liner top pkr @ 8772' landing nipple @ 525' 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 93 3183 3 -- 181 Subsequent to operation 122 ~ 433 149 -- 205 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ ' Service ^ Daily Report of Weli 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: none Contact Cody Gauer @ 263-4802 Pr9 ted Name C,~dy e Title Wells Engineer ~ Y ~ Si nature ~ Phone: 263-4802 '~~/ ~~> Date ~ S J.- ~. --^'~^'~ Pre a b Sha n All u-Drake 263-4612 ~,,..~ ~ ~SI~ ie.zQ ~ ._.~_~ ; ~ ~~~ v~T~ ? 'F 7~~~ Form 10-404 Revised 04/2006 - ~ ' Submit Original Only~~~~~ Can€~cc~~illips Alr3w?a~, =i x;. HANC.ER,72-~-}- -~ ~ NIPPLE,525 GAS UFT, 2,720 C~AS LIFT, 3,BBB SIIRFACE, 0.4,100 NIPPLE, 8,126 GAIIGE, 8,12B IOCATOR, B,1]4 SEALASSV, 8,776 D LEM, 8,165d.398 0 HANGER, 8,235-0,516 = KUP 1J-120 ~~ ,~ . _ ~ ;, - ~ ~~~~ ~ ~ ~~~ ~..a. r ,.; a- ~~ E a ,.. ; ~ ,.;: Wellbore API/UWI Fie10 Name IWell SWtus Prad/InJ WellType Incl (°) MD (ttKB) TD (max) (tl 500292335271 WESTSAK 'PROD 97.55 ~ 11,934.16 16,033.0 Comment HY3 (ppm) Date Annotatlon End Date KB1ird (tt) Rig Release Dete .. .. SSSV: NONE 0 7/1I2008 Last WO: 9/22/2008~ 3229 6/16/2007 ~~. Mnotation Depth (flKB) End Date AnnMrtion ~~ End Date Last Tag: Rev Reason: WORKOVER, GW C!O ~ I 10I52008 ,.:.: rr ~ y , ~ w ~~S#7i~`°= .\~. ~. ~.~ ., a ~ €- __,\~~..:" .: ~~~ . . ,. ~^~. imy,.. ' ~ Caeing Descnp6on St ing 0... Strmg ID ... Top (RKB) ,Set DepM (f...TSM Depth (ND) Stnng Wt... String Gr... Stnng Top Thi ..a -^ TUBING -~-~~ - 41 /2 3958 ~ r 00 81778 35849 7260 L80 IBTM .: ~8 _ . .. ~~~8 , , c~~..y.~ ~ \-°-;, , ._.:. ,,,,,, , „ ..: i,y , ,^, .: :. : t~. .._: ,,,, ~ .. ~~. .. ,:.: .,.., vu' ;% ~ ToP ~~h (ND) 7op I Top (IIKB) (RKB) ~~~I (°) ~~m Description ~ Comment ID Qn) ~ 22.3 22.3 -0.04 HANGER Vetco Gray Hanger 11" x 4.5" w/ 4.909" MCA Top Conn. Made up on full 3.900 524.8 524.3 5.98 NIPPLE 3.875"'DB' Nipple 3.875 8,126.31 3,569.1 ~ 72.99 NIPPLE 3.813"'DB' Nipple ; 3.812 8,175.8 3,SFI4.3 74.20 SEAI ASSY 8ondetl Seal Assembty W/ FUII MUte Shoe w/ "L.00' SpaCe out 3.S7U „ : , -- ~I~S~Td .... ,,. ,,.. , . . . `a. ,,^ , r ~ ....... . . > :.. .::-, , : . •.~~ ~ - `. ~ .; . . . .. ,~„ ., -: :~.,,;; . , ,,,, - • . ..'~: sna j j Top (ND) Btm (TVD) Dens i I Top (RKB) Btm (ttKB) (ftKB) (RKB) Zone Date (°h-~ Type CommeM 70,240.0 WSA2,1J-i20 ,5/17/2007 ' ~ 12,205A~i 3,873.8 3,90S.1 32.0SLOTS 2.5"xJ25",4circumferencialrows/R I 3" centers staggered 18 deg Y2,506.0 13,145.0 3,910J 3,929.4 WSA2, 1J-120 5/17/2007 32.0 SLOTS 2.5"x.125",4circumferencialrowslft I 3" centers staggered 18 deg 13,445.0 14,179.0 3,920.7i 3,924.OWSA2,1J-120 5/17I2007 32.O~SLOTSi 2.5"x.125",4circumferencialrows/ft ~ ~ ~ ' I ~~3" centers staggered 18 deg 14,350.0 . 15,113.0; 3,925.6 3,935.5 WS A2, 1J-120 5/17/2007 •, SLOTS 32.O 2.5'k .125",4 circumferencial rowsHt ~ j t i i 3" centers siaggered 18 deg j VIEW B LEM, 0,370.0,016 B HANGER, 8.870-8,955 ~ I (ND) Incl ~ OD ~ '~ Valve ~ Lateh '~ Size ~7RORunI I Stn Top (ttKB~'.. (ftK6) (°) I Make Motlel h~) "~ Serv TYPe ~ TYPe •, (ln) (Ps~) Comment Run Dffie 1 2,120.1 i 1,759.3 68.65 Camco KBG-2-1R 1 Gas Lift GLV BK I0.156 1,496.0, t011/2008 I ~ 2 3,888.4 2,395.2 66J2 Camm KBG-2-1R !, t Gas Lift OV . BK 114 OA~ I1011l2008 ~. C~ ~;~nQ,~,~~~~~~~s Time Log & Summary We/Niew Web Repvrting Re po rt Well Name: 1J-120 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 9/16/2008 9:30:00 AM Rig Release: 9/22/2008 4:00:00 AM 9/16/2008 24 hr Summarv Completed well 1J-101, RDMO, assembled LPR's on 13 5/8" BOP stack, set double mats on well 1J-120 and s otted ri over well, RU kill tank, um ed 420 bbis hot SW to kill well, ND tree and started NU BOPE. 08:00 10:00 2.00 MIRU MOVE RURD P Install single gate on stack, set rig mats on 1J-120 for hi h wellhead. 10:00 11:00 1.00 MIRU MOVE MOB P Move to 1J-120, spot and level rig over well, set up handy berm. Acceat 0930 hrs. 11:00 13:30 2.50 COMPZ RPCOM RURD P RU kill tank and hardline, PU lubricator and pul~ BPV, pressure test lines to 2,000 psi. SITP 600 psi, SICP 1,000 si. 13:30 17:00 3.50 COMPZ RPCOM CIRC P Pump 420 bbls 6% KCL seawater down tbg @ 6 bpm while venting IA to kill tank, shut down pump, tbg on vac, csg 50 psi, bleed off IA to kill tank and check for flow - no flow. RD and BD circ lines, set BPV. 17:00 00:00 7.00 COMPZ RPCOM NUND P ND tree, install test dart, MU spool and NU 13 5/8" BOP. 9/17/2008 RU on 1J-120, killed well, ND tree - NU BOPE and tested, unseated hanger and circ hot SW to clean tubing and 'ewel , POOH with 4 1/2" ESP com letion, rackin back tb in derrick. 00:00 02:00 2.00 COMPZ RPCOM NUND P Cont NU 13 5/8" BOPE and CO lower pipe rams to VBR 2 7/8" x 5 1 /2". 02:00 07:30 5.50 COMPZ WELCTI BOPE P Test and chart BOPE at 250 and 3 0, QQ ps; tested both ram sets and annular with 3 1/2" and 4 1!2" pipe, witness of test was waived by AOGCC Rep Jeff Jones at 17:00 hrs on 9-16-08. 07:30 09:30 2.00 COMPZ RPCOM RURD P Pull test dart, attempt to pull BPV,_ ~ressure under BPV,~umped 50 bbls down tb and ulled BPV. 09:30 12:00 2.50 COMPZ WELCTL CIRC P With well shut in tbg @ 30 psi, pumped 150 bbls of SW down tbg @ 7 bpm @ 50 psi. Pumped 130 bbls of 120 degree SW down IA , M/U landing joint. Bleed down 50 psi on IA to kill tank, BOLDS. Open rams and strip through annular with 800 si to unland han er. 12:00 13:30 1.50 COMPZ WELCTL OWFF P Monitor well and heat up additional SW on VAC truck. 13:30 14:30 1.00 COMPZ WELCTL CIRC P Pump 150 btrls of '!20 deg SW down IA @ 8.5 bpm, & 130 bbls down tbg (a~ 12 bpm. 14:30 00:00 9.50 8,201 714 COMPZ RPCOM TRIP P Pull hanger to floor, LD landing joint, RU E5P cable to spooler. POOH with 4 1/2" ESP com~letion, rackinc~ tb in derrick and drifting stands to 3.833". Using triple pipe displacement (7 bbis) for hole fill every 5 stands, and an additional 50 bbls ~er hour to well. 8/2008 RIH made clean out run, POOH, PU RIH with 245' ZXP and LEM assembly. 00:00 01:30 1.50 714 0 COMPZ RPCOM TRIP P Cont POOH with 4 1/2" ESP completion, stand back tbg and drift to 3.833" in derrick, using triple pipe displacement every 5 stands (7 bbls) lus 50 bbls eve hour to weii. 01:30 05:30 4.00 0 0 COMPZ RPCOM PULD P Break down ESP assembly and LD, clean floor, off load motor boxes and jewelry, load Baker tools, CO elevators, set wear ring, cont adding 50 b h SW to well. Recovered 11 SS bands, 3 protectrolizers, 2 flat guards, 154 cross coupler clamps. Missing 4 SS bands off ESP motor housin . 05:30 13:00 7.50 0 7,989 COMPZ RPCOM TRIP P PU washdown BHA (448') and RIH with 3 1/2" DP from derrick to 7,989'. 13:00 15:00 2.00 7,989 8,402 COMPZ RPCOM CIRC P Washed down from 7,989' to 8,385' pumping @ 4.5 bpm down back side w/charge pump and 5.5 bpm @ 2500 psi down DP. Recip across hook hanger w/side wash tool (snozzolator) 4 times. Wash from 8,385' to 8,402'. Saw 100 psi increase on DP when btm nozzle entered SBR. Tagged @ 8,402' RKB. U/down above hook was 135K/55K. 15:00 23:00 8.00 8,405 0 COMPZ RPCOM TRIP P POOH from 7,985' to 448' and LD BHA. 23:00 00:00 1.00 0 245 COMPZ RPCOM TRfP P PU and MU LEM and ZXP assembly 9/2008 RIH 30 fpm, oriented and set LEM assembly, pressure tested csg to 2,500 ps, POOH LD 3 1/2" DP and 4 3/4" DC's. 00:00 03:00 3.00 245 245 COMPZ RPCOM PULD P Cont MU Lem assembly (245') with running tools and MWD. CO s inners and elevators. 03:00 04:00 1.00 245 1,215 COMPZ RPCOM DHEQ P RIH 1 stnd 3 1/2" DP and perform shallow test on MWD. RIH 9 stnds to 1,214' and re-test as per request of MWD Rep. Electrical problem, trouble shoot MWD and transducer. 04:00 07:30 3.50 1,215 1,215 COMPZ RPCOM DHEQ T Electrical problem, trouble shoot MWD and transducer, wait on transducer being delivered from Deadhorse. Transducer re aired. 07:30 14:00 6.50 1,215 8,264 COMPZ RPCOM TRIP P Continue RIH from 1,215' to 8,170' w/ 9 DC's one stand below rotary for push if needed. • 14:00 16:00 2.00 8,264 8,075 COMPZ RPCOM DHEQ P At 8,170', up 150K, down 60K. MU top drive and pumped 120 gpm @ 500 psi for MWD. Found oriented @ 15R. Turned to 60R. RIH to 8,364', now oriented @ 70R. Continued down, pumping, and latched collet, now oriented 46R. PU & unlatched w/ 170K & oriented back to 60R. Latched again @ 26R. PU to 160K & break connection. Dropped 1.75" ball. Made connection and pumped ball to btm. MWD indicated 9L while displacing ball. Pressured up on DP to 3,400 psi to set ZXP @ 8,164' & released setting tool. Filled backside w/ charge pump & allowed to settle. Closed annular and PT csg & ZXP to 2,500 psi, OK. Bled off. POOH to ~ above ZXP at 8,075'. 16:00 18:00 2.00 8,075 8,075 COMPZ RIGMN7 SVRG P Cut and slip drili line. 18:00 00:00 6.00 8,075 3,565 COMPZ RPCOM TRIP P POOH LD DP 8~ DC's, from 8,075' to 3,565'. PU and RIH with 4 1/2" gas lift completion, 00:00 05:00 5.00 3,565 0 COMPZ RPCOM TRIP P Cont POOH LD 3 1/2" DP from 3,565', LD LEM running tools and MWD and off load same. 05:00 07:30 2.50 0 0 COMPZ RPCOM RURD P Load completion jewelry and tec-wire spooler, CO spools, string sheaves, pull wear rinq. 07:301 00:00 I 16.50 10 6,417 COMPZ RPCOM RCST P RIH with 4.5" completion seal, assembly to Guardian guage carrier. Splice and test TEC wire to guage. Continue RIH to 5,150' MD and install heat trace cable and test. (heat trace will sit at 3,015') Cont RIH from 5,150' to 6,417'. Installing clamps slower than normal due to tight fit or worn hydraulic/impact Space out, MU hanger, spotted corrosion inhibitor, landed hanger, tested 7 5/8" csg, ND BOP, NU tree and tested, RDMO, removed 13 5/8" BOP's for ri move. 00:00 09:30 9.50 6,417 8,177 COMPZ RPCOM RCST P Cont RIH from 6,417' to 8,177' with 4 1/2" gaslift completion w/ TEC wire & heat trace. Up/down above ZkP 125K/57K. Tag btm of sealbore & LD 'oints for s ace out. 09:30 1230 3.00 8,177 8,177 COMPZ RPCOM HOSO P MU space joints, hanger w/ fuli joint below and landing joint w/ side port iso sleeve. Install penetrators. Splice heat trace & TEC wire & connect to ~enetrators. 12:30 14:00 1.50 8,177 8,177 COMPZ RPCOM CIRC P Pumped 220 bbls 6% KCL seawater containing 1 % CRW-132 down backside. Sting in seals and fili backside in to BOP. Let air bubble out of backside. Drain stack thru IA valve. 14:00 16:00 2.00 8,177 8,177 COMPZ RPCOM HOSO P Guide pin did not line up hanger w/ side port properly. Lift hanger six inches and rotate top drive left roughly 1/4". Re-land hanger. Side port now aligned properly. RILDS. Set TWC in han er. 16:00 17:00 1.00 8,177 8,177 COMPZ RPCOM CIRC P RU pump to IA & PT to 1,000 psi for 5 minutes OK, in case SOV sheared before 1,500 psi. Pressure IA to 1500 si and SOV sheared. bled off ~ and RD circ lines. 17:00 19:00 2.00 8,177 8,177 COMPZ RPCOM NUND P ND 13 5/8" BOP and LD 5 stnds of tbg from derrick. Test tec-wire and heat trace. 19:00 22:00 3.00 8,177 8,177 COMPZ RPCOM NUND P NU adaptor and tree, test at 250 and 5,000 si. 22:00 23:30 1.50 8,177 8,177 COMPZ WELCTI OTHR P PuII l1NC, set BPV with lubricator. 23:30 00:00 0.50 8,177 8,177 COMPZ RPCOM RURD P Secure well, clean cellar area. Move Rig 3 off 1J Pad and toward 1D Pad. 00:00 00:30 0.50 COMPZ RPCOM RURD P Cont clean up and secure well site. 00:30 04:00 3.50 COMPZ MOVE DMOB P Pull rig off well, remove 13 5/8" BOP stack from cellar and place on skid, clean out cellar box, remove T mats and tarp. Nordic Rig 3 released at 04:00. SITP = 0, IA = 0, OA = 100 qSt. ~ 's. ~ • • ConocoPh ~ I I i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Sept 6, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~~7- ~ 4~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of fortn 10-404, Report of Sundry Operations. The cement was pumped August 28th, 2008. The corrosion inhibitor/sealant was pumped August 29th, Sept 5-6th,2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry Klei ConocoPhillips Well Integrity Projects Supervisor , ~ . ,, i ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 9/6/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitoN sealant date ft bbls ft al 1A-17 190-151 SF NA SF NA 2.55 8/29/2008 1A-18 190-153 21' 2.80 27" 8/28/2008 1A-20 190-162 21' 2.80 25" 8/28/2008 7.65 8/29/2008 1A-25 190-167 14' 1.90 25" 8/28/2008 7.65 8/29/2008 1J-101 205-182 6" NA 6" NA 1.28 9/5/2008 1J-102 206-110 7" NA 7" NA 1.70 9/5/2008 1J-103 206-114 7" NA 7" NA 1.28 9/5/2008 1 J-105 207-027 8" NA 8" NA 1.28 9/5/2008 1J-107 207-107 7" NA 7" NA 1.28 9/5/2008 1 J-109 206-050 14" NA 14" NA 8.08 9/5/2008 1J-115 206-122 10" NA 10" NA 2.55 9/5/2008 1 J-118 206-176 5" NA 5" NA 6.80 9/5/2008 1J-120 207-045 4" NA 4" NA 2.55 9/5/2008 1J-127 206-047 6" NA 6" NA 1.70 9/5/2008 1 J-135 207-038 8" NA 8" NA 1.70 9/6/2008 1J-136 206-154 9" NA 9" NA 1.70 9/6/2008 1J-137 206-108 12" NA 12" NA 5.10 9/6/2008 1J-154 205-035 4" NA 4" NA 4.67 9/6/2008 1 J-156 206-067 8" NA 8" NA 5.95 9/6/2008 1J-159 206-005 20" NA 20" NA 14.87 9/6/2008 1 J-160 207-015 20" NA 20" NA 7.23 9/6/2008 1 J-164 205-144 20" NA 20" NA 11.90 9/6/2008 1 J-176 207-099 6" NA 6" NA 1.28 9/6/2008 1 J-184 206-044 8" NA 8" NA 1.28 9/6/2008 ~- ~ ~ ~ , Robert Christensen ' s ~;; Production Engineering Tech. ~ Greater Kuparuk Unit , NSK-69 ~ ~ PO Box 196105 ~~~O~O~' ~'' ~~ i^~nchorage, AK 99519-6105 Phone:(907)659-7535 Fax:659-7314 August 8, 2008 Tom Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission 33 W. 7~` Ave. Ste. 100 Anchorage, AK 99501 Dear Mr. Maunder, ConocoPhillips Alaska, Inc. has changed the artificial lift method in the West Sak 1J-120, 1J-120L1, and 1J-120L2 multilateral oil production wells. Enclosed you will find 10-404 Reports of Sundry Well Operation recording the change in artificial lift method to GL (Gas lifted) due to a failed ESP (Electrical Submersible Pump). If you have any questions regarding this matter, please contact me at 659-7535. Sincerely, ~, r n ~ i : 'i ~_"~'~-`".----.... ~_ Robert D. Christensen Attachments ~ S h~ ' ~/~/J{~J ~ n ... n , ~ ~/~ ~ (/ . . . j 1! ~ ,{^.y f7i;f) . " STATE OF ALASKA ,'1,'~ ~ , `~~ ~ ~ ALASKA OIL AND GAS CONSERVATION C S~ION ~~.< . . REPORT OF SUNDRY WELL OPERATI.4NS 1. Operations Performed: Abandon ^ Repair Well ^ Plug Pertorations ~ S#imulate Q Other Q Failed ESP to GL Alter Casing ^ Pull Tubing ^ Pertorate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Pertorate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: '`Y , permit to Drill Number: ~l'XJ ConoCOPhllllps AlaskB, InC. Development ~ Exploratory ^ ~ 207-045 /$Q7~67~'g/ 3. Address: Strati ra hic Service g p ^ ^ , 6. API Number. P. O. Box 100360, Anchorage, Alaska 99510 ~ `~ 50-029-23352-00 7. KB Elevation (ft): 9. Well Name and Number: KB 109' ~ 1 J-120 8. Property Desl~ation\; 10. Field/Pool(s): 'ADL 25661, 25650 Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 15822' feet true vertical 3952' feet Plugs (measured) Effective Depth measured 15200 feet Junk (measured) true vertical 3935 feet Casing Length Size MD ND Burst Collapse CONDUCTOR 108' 20" 108' 108' SURFACE 4072' 10-3/4" 4100' 2470' WTERMEDIATE 9917' 7-5/8" 9945' 3872' A sd Slotted ~iner 6428' 4-1/2" 15200' 3935' Perforation depth: Measured depth: 10240'-12205; 12506'-13145'; 13445'-14179'; 14350'-15113' true vertical depth: 3874'-3908'; 3911'-3929'; 3921'-3924', 3926'-3936' Tubing (size, grade, and measured depth) 4.5", L80, 8202' MD. Packers & SSSV (type & measured depth) Baker "HRD" ZXP Liner top Packed Pkr = 8772' SSSV = None SSSV = None 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A 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 647 472 26 257 199 Subsequent to operation 2145 1832 165 910 228 14. Attachments ' 15. Well Class after work Copies of Logs and Surveys run _ Exploratory ^ Development 0 Service ^ Daily Report of Well Operations _X 16. WeII 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 N/A contact Robert D. Christensen Printed Name RQbert D. Ch~-istense Title Production Engineering Technician , Signature ~ ~;~~ ~ ~'~ , aPhone 659-7535 ~ Date ~ ~Q ~ ~ ~ --.~. / t~~'~~~= ~ - ~ ~ ~ . ~ . ~,~ ~ .~, ~~ ~ ~ Form 10-404 Revised 04/2006 ~ ~ ~ ~`"'' ~ ` t ` " Submit Original Only ~ ~~ . ~ 1 J-120 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 07/28/08 SET 4-1/2" SLIP STOP CATCHER @ 4008' WLM. PULLED SOV @ 2113' RKB. IN PROGRESS. 07/29/08 PULL DMY @ 3883' RKB, SET LV @ 2113' RKB & ATTEMPTED TO SET OV @ 3883' RKB, PULL SLIP STOP, OV IN SLIP STOP, DSO TO LEAVE WELL SHUT IN TILL CREW COMES TO RESET OV 08/02/08 SET 1/4° ORIFICE @ 3883' RKB. JOB COMPLETE. 08/06/08 Open Well - Return to service West Sal{ 1J-120 (PTD 207-045) Conversion To Gaslift Service ~ Page 1 of 1 ~ Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) 3snt: Thursday, July 24, 2008 10:22 AM To: 'NSK Prob{em Well Supv' Cc: NSK West Sak Prod Engr; CPF1 DS Lead Techs; NSK Prod Engr Tech; NSK Weli Integrity Proj Subject: RE: West Sak 1 J-120 {PTD 207-045) Conversion To Gasiift Service Martin, This will work. Tom From: NSK Probiem Weii Supv [mailto:n1617Ca1conocophil{ips.com] Sent: Thursday, July 24, 2008 10:19 AM To: Maunder, Thomas E (~OA) Cc: NSK West Sak Prod Engr; CPF1 DS Lead Techs; NSK Prod Engr Tech; NSK Well Integrity Proj; NSK Problem Welt Supv Subject: West Sak iJ-120 (PTD 207-045) Conversion To Gaslift Service Tom, The West Sak 1J-120 th~ough tubing ESP failed on 6l30/08 and was removed from the well on 7/21/08. CPAI is in the process of converting the well to gaslift service at this time. The well is permitted as having "backup gaslift" so our intent is to complete the work and subsequently submit a 10-~0~4 accompanied by a daily report of well operations. Ple~se r~spo~d if anything additipnal is required. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 9Q7-943-1720 / 1999 Pager 907-659-7000 #909 7/24I2008 ~ ~ To: State of Alaska WELL LOG TRANSMITTAL Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7t" Avenue, Suite 100 Ancharage, Alaska RE: MWD Formation Evaluation Logs 1 J-120 August 13, 2007 AK-MW-5005556 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23352-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 r'~ ~' ~ '~ ~ ~ ~-~, ~ a~; ~ ; ~- ~~~~~ Date: ~,~; ;~ " `~ ~JO! ,?.~~~~~ ~'st! ~?z ,:~~ ; ;r~a~~.c. ;;.JiT!!~i"!i~sirt'< ~~,''.L~?t`i'-~.;~' Signed: ao~--o~~~ # ~s3~/a ~ ~ ~ • Conc~COPh~~ll~ps July 18, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Reports for 1 J-120, 1 J-120L1, 1 J-120L2 Dear Commissioner: ~~~~~~~~ ~iUL ~ ~~ ~(lQ7 ~iaska Oi~ ~ ~~~ t ~~~s. C~mmission ~ncho~ag~ ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations of the Kuparuk West Sak wells 1 J-120 and 1 J-120L1 and 1 J-120L2. If you have any questions regarding this matter, please contact me at 265-6830 or Dennis Hartwig at 265-6862. Sincerely, ~.,. .~• ~ ~~~~~ - ~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling /~j/ c~['~~ v~v ~~P cJP / ` r --~ d~~ ~ ~ ~ ~-s. ~ ~ ~ Randy Thomas Kuparuk Drilling 7eam Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 RT/skad ~ STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION ~.~~~rv~~ ~~a~ ~ 4 zoo7 WELL COMPLETION OR RECOMPLETION REPOI~~~~I,~;~~~. ~~mrnissian 1a. Well Status: Oil ^/ Gas Plugged ~ Abandoned ~ Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No.ofCompletions: Tb. Well Class: ~~~~~,~~~~ Development ~ xploratory ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: June 16, 2007 d 12. Permit to Drill Number: 207-045 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: April 30, 2007 ` 13. API Number: 50-029-23352-00 " 4a. Location of Well (Governmental Section): SurFace: 1875' FSL, 2357' FEL, Sec. 35, T11N, R10E, UM ~ 7. Date TD Reached: ~ May 16, 2007 14. Well Name and Number: 1J-120 Top of Productive Horizon: 700' FNL, 1874' FEL, Sec. 36, T11 N, R10E, UM 8. KB (ft above MSL): Ground (ft MSL): 109' MSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 112' FNL, 2002' FEL, Sec. 25, T11 N, R10E, UM 9. Plug Back Depth (MD + ND): 15200' MD / 3935' ND West Sak Oil P001 ~ 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558854 ` y- 5945688 - Zone- 4 10. Total Depth (MD + ND): ~ 15822' MD / 3952' TYD " 16. Property Designation: ADL 25661,~25650 TPI: x- 564593 y- 5948439 Zone- 4 Total Depth: x- 564412 ' - 5954306 ~ Zone- 4 11. SSSV Depth (MD + ND): none 17. Land Use Permit: 471, 468 18. Directional Survey: Yes Q No ~ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (NDj: ~507' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/Res 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 34" 78.6# H-40 28' 80' 28' 80' 42" 36o sx AS 1 10.75" 45.5# L-80 28' 4100' 28' 2470' 13.5" 660 sx AS Lite, 18o sx DeepCRETE 7.625" 29.7# L-80 28' 9945' 28' 3872' 9.875" 552 sx DeepCRETE 4.5" 11.6# L-80 8772' 15200' 3699' 3935' 6.75" slotted liner 23. Open to production or injection? Yes ~ No If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET 4.5" 8202' 8772' blanks from 8772'-10240', 12205'-12505', 13144'-13445', 14179'-14350', 15133'-15200' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. slots from 10240'-12205', 12505'-13144', 13445'-14179', 14350'-15133' ` DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production July 9, 2007 Method of Operation (Flowing, gas lift, etc.) ESP producer- shares production with 1J-120L1 and 1J-120L2 Date of Test 7J12/2007 Hours Tested 12 hours Production for Test Period --> OIL-BBL 1415 GAS-MCF 179 WATER-BBL 58 CHOKE SIZE 100% GAS-OIL RATIO 158 Flow Tubing press. 231 psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL 2684 ' GAS-MCF 425 WATER-BBL 116 OIL GRAVITY - API (corr) not available 27. CORE DATA Conventional Core(s) Acquired? Yes No ~ Sidewall Cores Acquired? Yes No ~ If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. CC~flr??~_rTi!?Y Dr~?: . rvoNE ' uE~~~~~~ ~ ~~~~--- Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE ~? ~ 7•,Z7 O~ 0 R 1 G I N A l.. ~~~ ~~L AUG U 8 20D7 ~'~'`~i~~ ,~~T/~r~'~ ~ 28. GEOLOGIC MARKERS (List ail formations and mar rs encountered): 29. FORMATION TESTS NAME MD lVD Well tested? Yes Q No If yes, list intervals and formations tested, PerrrlBfrost - Top surface surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1655' 1507' (Est.) needed, and submit detailed test information per 20 AAC 25.071. T3 1898' 1658' (est.) K15 2652' 1980' (est.) Ugnu C 6035' 3017' Ugnu B 7311' 3360' Ugnu A 7435' 3394' K13 7525' 3417' West Sak D 8240' 3601' West Sak C 8469' 3651' West Sak B 8667' 3683' West Sak A4 8g75' 3728' N/A West Sak A3 9318' 3776' West Sak A2 9856' 3861' Formation at total depth: Kuparuk A2 sand ` 30. LtST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, slotted liner detail sheet 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ContaCt: Dennis Hartwig @ 265-6862 Printed Name Ran Thomas Title: Drillinq Team Leader ~~~ ~~ Signature ne / Date ~ ' - ~G1 d ! ~ INSTRUCTIONS Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 weli sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Ke~ly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a Iist of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 i ~ Halliburton Company Survey Report ~;s~o~npany: Gonncol~tlips AlasKa tnc. ~ ~~~ ~~ Da~ 711Qf~~07 ~: ~'~me '~~=2~~44 ~~~ `.Pag~: 1 ( -F~td: k~c~patztk,~iYe~ ~'Jr~rt ' ~ ~ ~ , . 1;~12D, Trtie~ I~rth - ~ ~ Co~~^d~irta~~ Refer~u~e: '~: i~iie[(, ~-~ Kuparuk'[J Pad , Verti~[~'Vi1~~te~r~~ce '[J-12~;;it7~,t} ~Ve1i: 1J-12[? ~eti~rn~V~}Referenc+e Well(Q.ODN~f)~}~~~304~~ ~:~'eilpetlt: 1.t-'I ~~ :: ~ Survey ~akula~ion Method Minimum G€~rv~titre bb :OraCle ~ Field: Kuparuk River Unit I North Slope Alaska United States ! Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 I Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: 1 J-120 Slot Name: Well Position: +N/-S -232.13 ft Northing: 5945688.02 ft Latitude: 70 15 43.975 N +E/-W 61.75 ft Easting : 558853.50 ft Longitude: 149 31 27.210 W ~ Position Uncertainty: 0.00 ft ~ Wellpath: 1J-120 Drilled From: Well Ref. Point 500292335200 Tie-on Depth: 28.00 ft Current Datum: 1 J-120: Height 109.00 ft~ Above System Datum: Mean Sea Level Magnetic Data: 4/28/2007 Declination: 23.38 deg ~ Fieid Strength: 57609 nT Mag Dip Angle: 80J9 deg I Verticai Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg ~ _ 28.00 0.00 0.00 0.00 _~ Survey Program for Definitive Wellpath - -j Date: 5/22/2007 Validated: No Version: 4 Actual From To Survey Toolcode Tool Name ft ft 50.00 923.00 1J-120 gyro (50.00-923.00) CB-GYRO-SS Camera based gyro single shot ~ ~ 954.87 15783.50 1J-120 (954.87-15783.50) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC ~ Survey " 1431f `. Incl riz~m „' ~'~L3 ; ; : Sys TT'3} 1~TfS ?' ~tVl~ ? f Map1Y ; ' MapE , fi~wl 'ft de9 d~g . : ~ ..~ ft ,,, , :. ft ' ft ' ft ~, ft ft' ~ ~ 28.00 0.00 ~~ 0.00 28.00 -81.00 ~ 0.00 ~ 0.00 ° 558853.50 5945688.02 ~ TIE LINE 50.00 0.16 39.83 50.00 -59.00 0.02 0.02 5945688.04 558853.52 CB-GYRO-SS 100.00 0.19 351.75 100.00 -9.00 0.16 0.05 5945688.18 558853.55 CB-GYRO-SS 172.00 0.04 273.66 172.00 63.00 0.28 0.01 5945688.30 558853.51 CB-GYRO-SS 263.00 0.04 142.67 263.00 154.00 0.26 0.00 5945688.28 558853.50 CB-GYRO-SS 354.00 1.15 96.21 353.99 244.99 0.13 0.92 5945688.16 558854.42 CB-GYRO-SS 446.00 4.12 100.99 445.89 336.89 -0.60 5.09 5945687.46 558858.59 CB-GYRO-SS 538.00 6.46 100.53 537.49 428.49 -2.17 13.42 5945685.95 558866.94 CB-GYRO-SS I 630.00 9.82 99.46 628.55 519.55 -4.41 26.25 5945683.82 558879.78 CB-GYRO-SS I 733.00 14.84 103.55 729.14 620.14 -8.95 47.75 5945679.45 558901.32 CB-GYRO-SS 828.00 18.87 101.76 820.04 711.04 -14.93 74.63 5945673.67 558928.24 CB-GYRO-SS 923.00 20.86 98.97 909.39 800.39 -20.99 106.33 5945667.86 558959.98 CB-GYRO-SS 954.87 22.20 93.05 939.04 830.04 -22.29 117.94 5945666.65 558971.60 MWD+IFR-AK-CAZ-SC 1051.17 25.72 90.70 1027.03 918.03 -23.52 157.01 5945665.73 559010.68 MWD+IFR-AK-CAZ-SC 1099.38 29.05 91.35 1069.83 960.83 -23.92 179.18 5945665.50 559032.84 MWD+IFR-AK-CAZ-SC i 1145.17 30.26 92.79 1109.62 1000.62 -24.75 201.82 5945664.86 559055.49 MWD+IFR-AK-CAZ-SC ~ 1197.33 30.44 94.39 1154.63 1045.63 -26.40 228.12 5945663.41 559081.80 MWD+IFR-AK-CAZ-SC i 1241.36 31.58 95.90 1192.37 1083.37 -28.44 250.71 5945661.55 559104.40 MWD+IFR-AK-CAZ-SC 1336.70 35.38 99.75 1271.89 1162.89 -35.68 302.77 5945654.71 559156.51 MWD+IFR-AK-CAZ-SC i 1393.94 37.25 100.67 1318.01 1209.01 -41.69 336.13 5945648.96 559189.91 MWD+IFR-AK-CAZ-SC ! 1433.31 40.32 100.99 1348.69 1239.69 -46.33 360.35 5945644.51 559214.16 MWD+IFR-AK-CAZ-SC 1481.93 42.75 101.17 1385.08 1276.08 -52.53 391.98 5945638.56 559245.84 MWD+IFR-AK-CAZ-SC ~ 1526.58 43.82 100.68 1417.59 1308.59 -58.33 422.04 5945633.00 559275.94 MWD+IFR-AK-CAZ-SC 1587.78 45.44 100.83 1461.14 1352.14 -66.35 464.28 5945625.31 559318.24 MWD+IFR-AK-CAZ-SC ~ T624.21 48.69 10'l.15 1485.95 1376.95 -71.44 490.46 5945620.43 559344.45 MWD+IFR-AK-CAZ-SC I 1671.73 48.99 101.65 1517.23 1408.23 -78.51 525.53 5945613.63 559379.57 MWD+IFR-AK-CAZ-SC j i 1718.45 49.30 101.39 1547.79 1438.79 -85.56 560.15 5945606.84 559414.25 MWD+IFR-AK-CAZ-SC 1764.18 50.22 100.65 1577.33 1468.33 -92.24 594.42 5945600.44 559448.56 MWD+IFR-AK-CAZ-SC 1811.78 52.25 100.28 1607.13 1498.13 -98.97 630.91 5945593.99 559485.11 MWD+IFR-AK-CAZ-SC ~ ~ Halliburton Company Survey Report ~ ~ Halliburton Company Survey Report . i:.~ampady: Cnn~f~tupips Ai~a fn~. ~ ~~ I~at~ ~ . 7i,1 Qf2~107 ~~-: Tfine 1~.26:4+~ ~ _ ~~ Page~ 3 i~ld: ';` Ku~Sarukf~uE*r (Jrrrt ' Ga=nr~inate~~iE,)Refer~e: ' UU~:Its` 1J•120, Ttu~ Ntar#h i ,. ; i sit~: ;ICuparuk ~CJ; ~ ., P~tt ~'c~ficai {'~'i~~ ~efere~r€e: ' 1J-f2q: '~U9:t3, 4'veli: "IJ='#~C} ~e~fun (V~}I~e~"c~t~ce; Wett (f~.~f~~*I 0;40E,4~t~4i0.X6} =' ~eligntl~: i;I-1~ Survey C$teulatian l~te[6od: : Mirtirtiwr~l GUrv~ture ~ T~r. t~rac[e Survey 1~: Incl Azim ' 1'~TI) ' SysTV13 N7S. ! F.1~' ' '1yf~plv MaPE T~i '' #t : ¢eg ~ieg ft ft'', 'fk,;; ft ~``ft ft' 6218.97 73.83 67.04 3067.76 295876 -484.93 4711.44 5945239.97 563568.14 MWD+IFR-AK-CAZ-SC 6315.12 74.01 64.14 3094.39 2985.39 -446.75 4795.56 5945278.80 563651.95 MWD+IFR-AK-CAZ-SC 6410.12 74.60 60.85 3120.10 3011.10 -404.52 4876.67 5945321.67 563732.71 MWD+IFR-AK-CAZ-SC ~ 6505.50 74.53 58.41 3145.49 3036.49 -358.04 4955.99 5945368.76 563811.66 MWD+iFR-AK-CAZ-SC ( 6598.83 74.59 55.01 3170.34 3061.34 -308.67 5031.17 5945418.71 563886.45 ~ MWD+IFR-AK-CAZ-SC ~ 6691.65 74.21 52.21 3195.31 3086.31 -255.64 5103.13 5945472.30 563957.98 MWD+IFR-AK-CAZ-SC ~ 6785.07 74.13 49.76 3220.79 3111.79 -199.06 5172.96 5945529.41 564027.36 MWD+IFR-AK-CAZ-SC I 6879.36 74.73 46.34 3246.11 3137.11 -138.35 5240.50 5945590.64 564094.42 MWD+IFR-AK-CAZ-SC ~ 6974.35 74.65 43.10 3271.20 3162.20 -73.26 5304.96 5945656.23 564158.36 MWD+IFR-AK-CAZ-SC 7069.05 74.78 39.86 3296.17 3187.17 -4.83 5365.45 5945725.12 564218.31 MWD+IFR-AK-CAZ-SC 7165.40 74.91 36.24 3321.36 3212.36 68.39 5422.76 5945798.78 564275.04 MWD+IFR-AK-CAZ-SC 7260.97 74.47 32.82 3346.61 3237.61 144.31 5475.00 5945875.10 564326.68 MWD+IFR-AK-CAZ-SC 7357.84 73.94 30.17 3372.98 3263.98 223.78 5523.70 5945954.94 564374.75 MWD+IFR-AK-CAZ-SC 7452.31 74.45 27.61 3398.71 3289.71 303.36 5567.61 5946034.86 564418.03 MWO+IFR-AK-CAZ-SC 7546.25 74.66 25.27 3423.73 3314.73 384.43 5607.92 5946116.23 564457.71 MWD+IFR-AK-CAZ-SC 7638.82 74.91 22.70 3448.03 3339.03 466.04 5644.23 5946198.11 564493.37 MWD+IFR-AK-CAZ-SC 7733.59 74.60 20.35 3472.95 3363.95 551.09 5677.77 5946283.41 564526.25 MWD+IFR-AK-CAZ-SC 7828.86 74.59 17.30 3498.27 3389.27 638.01 5707.41 5946370.55 56455520 i MWD+IFR-AK-CAZ-SC 7924.30 75.37 15.21 3523.00 3414.00 726.50 5733.20 5946459.23 564580.30 MWD+IFR-AK-CAZ-SC ~ ~ 8019.57 75.93 12.01 3546.62 3437.62 816.19 5754.92 5946549.09 564601.31 MWD+IFR-AK-CAZ-SC i 8115.81 75.94 8.34 3570.02 3461.02 908.06 5771.40 5946641.07 564617.08 MWD+IFR-AK-CAZ-SC 8210.30 75.04 7.35 3593.69 3484.69 998.68 5783.89 5946731.77 564628.85 MWD+IFR-AK-CAZ-SC 8304.16 77.33 8.70 3616.10 3507.10 1088.92 5796.62 5946822.11 564640.88 MWD+IFR-AK-CAZ-SC 8398.85 77.46 5.82 3636.77 3527.77 1180.58 5808.30 5946913.84 564651.83 MWD+IFR-AK-CAZ-SC 8493.80 79.84 3.76 3655.46 3546.46 1273.33 5816.06 5947006.65 564658.87 MWD+IFR-AK-CAZ-SC 8587.33 81.34 2.43 3670.75 3561.75 1365.47 5821.04 5947098.81 564663.13 MWD+IFR-AK-CAZ-SC 8682.92 81.66 0.90 3684.88 3575.88 1459.96 5823.79 5947193.31 564665.14 MWD+IFR-AK-CAZ-SC 8778.86 80.66 358.24 3699.63 3590.63 1554.75 5823.08 5947288.08 564663.69 MWD+IFR-AK-CAZ-SC 8872.99 82.10 357.68 3713.73 3604.73 1647.76 5819.76 5947381.05 564659.65 MWD+IFR-AK-CAZ-SC 8968.94 81.98 357.26 3727.02 36'l8.02 1742.69 5815.57 5947475.94 564654.71 MWD+IFR-AK-CAZ-SC ~ I 9065.35 81.91 357.18 3740.53 3631.53 1838.04 5810.94 5947571.24 564649.34 MWD+IFR-AK-CAZ-SC ~ i 9161.47 81.79 356.02 3754.16 3645.16 1933.02 5805.30 5947666.16 564642.96 MWD+IFR-AK-CAZ-SC ~ i 9255.26 81.97 355.22 3767.41 3658.41 2025.59 5798.21 5947758.67 564635.14 MWD+IFR-AK-CAZ-SC ' 9350.73 81.85 356.34 3780.84 3671.84 2119.86 5791.25 5947852.87 564627.45 MWD+IFR-AK-CAZ-SC I 9446.42 80.54 355.79 3795.49 3686.49 2214.19 5784.76 5947947.14 564620.23 MWD+~FR-AK-CAZ-SC ~ 9541.09 80.36 356.60 3811.20 3702.20 2307.34 5778.57 5948040.23 564613.30 MWD+IFR-AK-CAZ-SC 9637.34 80.86 355.83 3826.90 3717.90 2402.10 5772.30 5948134.92 564606.29 MWD+IFR-AK-CAZ-SC 9730.26 81.16 356.55 3841.42 3732.42 2493.67 5766.20 5948226.44 564599.48 MWD+IFR-AK-CAZ-SC 9825.87 81.10 357.44 3856.16 3747.16 2588.01 5761.25 5948320.72 564593.79 MWD+IFR-AK-CAZ-SC 9920.69 83.59 359.01 3868.79 3759.79 2681.93 5758.34 5948414.61 564590.15 MWD+IFR-AK-CAZ-SC 9984.73 86.31 0.69 3874.43 3765.43 2745.71 5758.18 5948478.38 564589.49 MWD+IFR-AK-CAZ-SC 10033.06 89.57 1.18 3876.17 3767.17 2793.99 5758.96 5948526.67 564589.90 MWD+IFR-AK-CAZ-SC 10127.41 90.13 359.35 3876.41 3767.41 2888.34 5759.40 5948621.00 564589.60 MWD+IFR-AK-CAZ-SC ~ 10220.92 92.23 356.44 3874.49 3765.49 2981J5 5755.97 5948714.38 564585.44 MWD+IFR-AK-CAZ-SC I j 10314.46 91.24 354.82 3871.66 3762.66 3074.97 5748.84 5948807.53 564577.58 MWD+IFR-AK-CAZ-SC j 10408.33 88.52 354.49 3871.85 3762.85 3168.42 5740.10 5948900.90 564568.11 MWD+IFR-AK-CAZ-SC i 10501.66 88.52 355.32 3874.26 3765.26 3261.35 5731.81 5948993.76 564559.10 MWD+IFR-AK-CAZ-SC 10594.95 89.57 356.41 3875,82 3766.82 3354.39 5725.09 5949086.72 564551.65 MWD+IFR-AK-CAZ-SC 10688.64 88.03 358.31 3877,78 3768.78 3447.95 5720.77 5949180.24 564546.60 MWD+IFR-AK-CAZ-SC 10781.25 88.52 358.79 3880.57 3771.57 3540.49 5718.43 5949272.75 564543.54 MWD+IFR-AK-CAZ-SC 10874.11 88.89 359.31 3882.67 3773.67 3633.31 5716.89 5949365.55 564541.27 MWD+IFR-AK-CAZ-SC 10967.37 87.78 0.58 3885.38 3776.38 3726.53 5716.80 5949458.75 564540.46 MWD+IFR-AK-CAZ-SC 11060.60 88.28 0.07 3888.58 3779.58 3819.70 5717.33 5949551.92 564540.26 MWD+IFR-AK-CAZ-SC _ ~ ~ Halliburton Company Survey Report ~ ~ Halliburton Company Survey Report Survey 15783.50 89.08 1.52 3951.27 3842.27 8535.56 5624.58 5954266.45 564410.66 MWD+IFR-AK-CAZ-SC 15822.00 , 89.08 1.52 3951.89 . 3842.89 8574.04 5625.60 5954304.94 _ 564411.38 , PROJECTED to TD ~ ~ Ct~rto~oPhi~Iips We/lview Web RePOrting Weli Name: 1J-120 Job Type: DRILLING ORIGINAL Time Log Summary 04/29/2007 14:00 15:00 1.00 0 0 MIRU MOVE RURD P Disconnected service loops and lines, blew down ri in re eration to move. 15:00 18:00 3.00 0 0 MIRU MOVE DMOB P Moved rig complex's off 1J-105 and s otted on ad 18:00 21:30 3.50 0 0 MIRU MOVE MOB P Moved sub base off 1J-105 and s otted overwell 1J-120 21:30 00:00 2.50 0 0 MIRU MOVE RURD P Set in rig complex's and started to connecting service lines and mud lines. 04/30/2007 00:00 02:30 2.50 0 0 MIRU MOVE RURD P Fin. connecting rigs service loops and lines, bermed rock washer and completed rig acceptance check list. Acce ted ri at 02:30 hrs 02:30 06:30 4.00 0 0 MIRU MOVE RURD P NU diverter and loaded pipeshed with 195 'ts of 5" DP and stra ed same. 06:30 08:30 2.00 0 0 MIRU MOVE RURD P Changed over top drive saver sub and iron rou hneck to 5" DP. 08:30 08:45 0.25 0 0 MIRU MOVE SFTY P Held PJSM on PU and standing back DP. 08:45 19:30 10.75 0 0 MIRU MOVE RURD P PU and stood back 65 stds of 5" DP, 6-stds of 5" HWDP with jars and 1 std of 8" NMFDC's. Cleared and cleaned ri floor. 19:30 20:00 0.50 0 0 MIRU WELC7 OTHR P Function tested diverter and perFormed Koomey test. Initiai pressure 3,000 psi, 1,800 psi after functioning diverter, took 45 sec's to build 200 psi, 3 min 21 sec's for full recovery, 5-nitrogen bottles ave 2,150 psi. NOTE: Jeff Jones with AOGCC waived witnessing of the test. 20:00 21:30 1.50 0 0 SURFA DRILL PULD P MU 13 1/2" bit #1 on 8" motor with 1.5 deg bend, RIH with stab and flt sub to 35'. 21:30 21:45 0.25 0 0 SURFA DRILL OTHR P Flooded the conductor checking lines for leaks then pressure tested the mud line and stand pipe to 3,000 psi and ck'd ok. 21:45 22:15 0.50 0 0 SURFA DRILL CIRC P RIH and tagged ice inside the conductor at 87' then cleaned out to 108'. 22:15 00:00 1.75 0 143 SURFA DRILL DRLG P Spudded well at 22:15 hrs and drilled 13 1/2" hole from 108' to 143', ADT 1.1 hrs. 05/01/2007 00:00 02:00 2.00 143 225 SURFA DRILL DRLG P Drilled 13 1/2" hole from 143' to 225' MD, ADT 1.92 hrs 02:00 02:30 0.50 225 35 (SURFA DRILL TRIP P POOH from 225' to motor /' 05/01/2007 02:30 03:15 0.75 35 225 SURFA DRILL PULD P Fin MU BHA#1, MU MWD, oriented and u loaded same RIH to 225' 03:15 03:30 0.25 225 225 SURFA DRILL RURD P RU Sperry Sun's Gyro and e-line. 03:30 12:00 8.50 225 702 SURFA DRILL DDRL P Directionally drilled 13 1/2" hole from 225' to 702' MD/ 699' ND, (477') ART 1.22 hrs, AST 4.4 hrs. Ran 6 G ro's takin 8 surve s. 12:00 00:00 12.00 702 1,340 SURFA DRILL DDRL P Directionally drilled 13 1/2" hole from 702' to 1,340' MD/1,280' ND, (638') ART 1.48 hrs, AST 6.21 hrs. Ran 2 Gyro's taking 3 surveys. RD Gyro at 23:00 hrs. 05/02/2007 00:00 12:00 12.00 1,340 2,340 SURFA DRILL DDRL P Directionally drilled 13 1/2" hole from 1,340' to 2,340' MD/1,838' TVD, (910') ART 3.39 hrs, AST 4.62 hrs. 12:00 18:00 6.00 2,340 2,847 SURFA DRILL DDRL P Directionally drilled 13 1/2" hole from 2,340' to 2,847' MD/2,012' ND, (507') ART 2.78 hrs, AST .35 hrs. Saw sign of hydrates at 2,528' MD/1,899' ND, had gas spike of 1,237 units then dropped out, 9.0 ppg MW gas cut to 8.4 ppg. White drlg at 2,847' in K-15 sand had thick oil blinding off the shakers. 18:00 18:45 0.75 2,847 2,847 SURFA DRILL OTHR NP Changed out shaker screens due to thick oil blindin them off. 18:45 00:00 5.25 2,847 3,106 SURFA DRILL DRLG P Directionally drilled 13 1/2" hole from 2,847' to 3,106' MD/2,104' ND, (259') ART 3.54 hrs, AST .5 hrs. While drilling at 650 gpm had 1,750 psi on btm, at 600 gpm had 1,600 psi and at 550 gpm had 1,400 psi. varyied rates while rotating and slowed rate while slidin . 05/03/2007 00:00 10:45 10.75 3,106 4,110 SURFA DRILL DDRL P Directionally drilled 13 1/2" hole from 3,106' to 4,110' MD/2,473' TVD, (1,004') (10 3/4" csg pt.) ART 4.47 hrs, AST 2.89 hrs. 10:45 11:00 0.25 4,110 4,110 SURFA DRILL OWFF P Monitored well-static, took survey on btm. 11:00 15:30 4.50 4,110 723 SURFA DRILL REAM P Backreamed out of the hole from 4,110' to BHA at 723', BROOH at 80 rpm's, 600 gpm, ICP 1,550 psi. FCP 1,300 si, no roblems BROOH. 15:30 17:45 2.25 723 65 SURFA DRILL PULD P POOH LD ghost reamer, 4 stds of HWDP and 1 std of NMFDC's, stood back 2 stds of HWDP and 'ars 17:45 20:00 225 65 0 SURFA DRILL PULD P Downloaded MWD and fin LD BHA #1, cleared and cleaned ri floor. 20:00 21:45 1.75 0 0 SURFA CASIN RURD P RU to run 10 3/4" csg, MU Franks fill up tool and changed out elevator bales. 21:45 22:00 0.25 0 0 SURFA CASIN( SFTY P Held PJSM with rig crew and tong operator on csg running details and hazard assessment for the iob. ~ 05/03/2007 22:00 00:00 2.00 0 1,100 SURFA CASIN RNCS P MU 3jts 10?" 45.5#, L-80 BTC csg and shoe track and thread locked same RIH to 80' and checked floats. Cont. RIH with 10 3/4" csg running centralizers erwell Ianto1,100'. 05/04/2007 00:00 04:15 4.25 1,100 4,110 SURFA CASIN( RNCS P Cont. RIH from 1,100' with 10 3/4" 45.5#, L-80, BTC csg, broke circ every 10 jts while getting up and down wts, tagged btm with csg at 4,110', washed down a couple of jts thru base of permafrost then cont RIH, no other problems RIH, ran 104 total jts of csg , P/U = 205k, S/O =60k Ran 25 bowspring centralizers and 2 turbolizers with 5 stop rings per well lan, cs lanned to be set with sli s. 04:15 05:45 1.50 4,110 4,107 SURFA CEME CIRC P PU to setting depth of 4,?07' and circ bottoms up thru Franks fill up tool staging pump rate up to 6 bpm at 375 psi, reciprocated pipe (P/U = 195k, 05:45 06:45 1.00 4,107 4,107 SURFA CEME~ RURD P RD Franks fill up tool and MU Dowell cement head. 06:45 08:15 1.50 4,107 4,107 SURFA CEME~ CIRC P Cont to circ and condition mud for cementing, staged pump rate up to 6.5 bpm at 385 psi initial mud was 9.4 ppg, 195 vis, PV 22 and YP of 44, conditioned mud to 9.1 ppg, 45 vis, PV 10 and YP 11, held PJSM with crew, Dowell and ASRC truck drivers on cement 'ob while circ. 08:15 11:00 2.75 4,107 4,107 SURFA CEME DISP P Dowell pumped 10 bbis of CW 100 then pressure tested lines to 3,500 psi, cont to pump 40 add. Bbls of CW 100 at 8.3 ppg and pumped 50 bbls of 10.5 ppg mudpush with red dye at 4 bpm at 225 psi. then dropped bottom plug. Mixed and pumped 529 bbls, 660 sx of Arctic set lite cement at 10.7 ppg and 4.57 yield with additives at 6.5 bpm at 120 psi, continued mixing and pumping 79 bbls, 180 sx of Deepcrete cement at 12.0 ppg and 2.47 yield with additives at 5 bpm at 120 psi.. Shut down and dropped top plug. Reciprocated pipe and had full returns. • 05/04/2007 11:00 12:15 1.25 4,107 4,100 SURFA CEME~ DISP P Dowell chased plug with 20 bbls of water then turned it over to the rig and rig cont. to displace cement with 9.1 ppg mud at 6.5 bpm, initial pressure was 300 psi, max pressure at 6.5 bpm was 925 psi, 200 bbls into displacement began to loose returns slowly, slowed rate to 3 bpm and had approx. 1 bpm returns, bumped plug on calc displacement of 369 bbis, pressured up to 1450 psi and held for three minutes, bled off and checked floats-OK. CIP at 12:15 hrs PM, had 0 bbls of good 10.7 ppg cement back at surface. Reciprocated pipe 50 bbls into tail cement with 170 bbis of lead cement outside of the shoe. Pipe stuck 7' from planned depth landing csg with shoe at 4,100' and flt collar at 4,017'. 12:15 13:30 1.25 4,100 4,100 SURFA CEME~ OTHR T Notified CPAI and AOGCG of no cement to surface while gathering up 1 1/8" H dril tb . 13:30 15:45 2.25 4,100 4,100 SURFA CEME~ OTHR T RU then RIH with 1 1/8" Hydril tbg, tagged up at 167' and was unable to go deeper, flushed annulus with 60 bbls of water and at btms up had red d e at surface from mud ush. 15:45 16:30 0.75 4,100 4,100 SURFA CEME DISP T Dowell pumped 55.9 bbls of 10.7 ppg Lead slurry. Shut down when 10.7 ppg CMT returns reached pits. NOTE: Bob Noble with AOGCC witnessed the top 'ob. 16:30 17:30 1.00 4,100 4,100 SURFA CEME~ RURD P RD cementers and flushed out diverter. 17:30 18:30 1.00 0 0 SURFA WELCT NUND P ND and PU diverter, set 10 3/4" emer enc sli s with 90K over blk wt. 18:30 19:00 0.50 0 0 SURFA WELCT OTHR P Drained and made rough cut on 10 3/4" cs . 19:00 23:00 4.00 0 0 SURFA WELC NUND P LD cut jt and fin. ND diverter, set out diverter from cellar and made final cut on cs . 23:00 00:00 1.00 0 0 SURFA WELC OTHR P Began to weld on wellhead adapter flan e. 05/05/2007 ~0:00 00:30 0.50 0 0 SURFA WELCT OTHR P Fin. welding on wellhead adapter 00:30 10:30 10.00 0 0 SURFA WELCT OTHR P Waited on wellhead to cool down, checked after 6.5 hrs and Vetco Gray rep recommended waiting an add. 3 hrs. SIM-OPS: PU and stood back 40 stds of 5" DP and 1 std of NMFDC's, slip and cut 58' of drlg line, serviced top drive then tested choke manifold to 250 psi low and 3,000 psi hiqh. 05/05/2007 10:30 11:30 1.00 0 0 SURFA WELC NUND P NU Vetco Gray MB 222 wellhead and oriented same, tested weld on adapter to 1,600 psi for 10 min then tested sea~ sub to 5,000 psi for 10 min and tested ok. 11:30 13:30 2.00 0 0 SURFA WELCT NUND P NU BOP stack and riser. 13:30 16:30 3.00 0 0 SURFA WELC BOPE P RU and tested BOPE, tested rams, annular and floor valves to 250 psi low and 3,000 psi high, tested with 4", 5" and 7 5/8" test jts, tested koomey, had 3,000 psi to start, 1,950 psi after functioning rams, took 38 sec's to build 200 psi, 2 min. 43 sec's for full recovery, have 5 nitrogen bottles ave 2,150 psi. NOTE: Bob Noble with AOGCC waived witnessin of the test. 16:30 17:00 0.50 0 0 SURFA DRILL OTHR P Installed long wear bushing. 17:00 21:00 4.00 0 357 SURFA DRILL PULD P PU and MU 9 7/8" Geopilot BHA #2 RIH to 357', MU bit #2 on Geopilot and MWD with DGR and PWD, uploaded same, RIH with 1 std of NMFDC's to 357'. 21:00 21:30 0.50 357 542 SURFA DRILL TRIP P RIH from 357' to 542' 21:30 22:00 0.50 542 542 SURFA DRILL DHEQ P Broke in Geopilot bearings and shallow tested MWD, blew down top drive 22:00 00:00 2.00 542 2,728 SURFA DRILL TRIP P RIH from 542' to 2,728', MU ghost reamer and vibration sub after std 16 at 1,870' back from the bit and retested Geo ilot deflection at 2,728'. 05/06/2007 00:00 00:30 0.50 2,728 3,998 SURFA DRILL TRIP P RIH from 2,728' and washed down at 1 bpm tagging up on cmt above piugs at 3,998' FC at 4,015' . 00:30 01:15 0.75 3,998 3,998 SURFA DRILL CIRC P Circ hole evening MW in and out at 9.0 ppg, circ at 124 spm, 525 gpm at 1,320 psi, rot wt 84K, up wt 118K, dn wt 62K. 01:15 02:00 0.75 3,998 3,998 SURFA CASINC DHEQ P RU and tested 10 3/4" to 3,000 psi for 30 min, ood test. 02:00 06:15 4.25 3,998 4,110 SURFA CEME COCF P Drilled out plugs, flt collar at 4,015', shoe track and shoe, cleaned out to TD at 4,110', 06:15 06:30 0.25 4,110 4,130 SURFA DRILL DRLG P Drilled 20' of new hole to 4,130', ADT .12 hrs 06:30 07:15 0.75 4,130 4,130 SURFA DRILL CIRC P Displaced hole overto reconditioned 9.0 ppg LSND mud, circ at 525 gpm at 1,400 si. 07:15 07:45 0.50 4,130 4,130 SURFA DRILL LOT P RU and performed a LOT to 14.6 ppg EMW, 720 psi with 9.0 ppg mud at 2,470' TVD. 07:45 08:45 1.00 4,130 4,283 INTRM1 DRILL DDRL P Drilled 9 7/8" hole from 4,130' to 4,283' MD! 2,525' TVD 153' ADT .63 hrs 08:45 09:30 0.75 4,283 4,283 INTRM1 DRILL OTHR T Trouble shoot MWD signal, decision was made to POOH. • ~ 05/06/2007 09:30 12:00 2.50 4,283 173 INTRM1 DRILL TRIP T POOH from 4,283' to BHA at 173', LD ghost reamer and vibration sub while POOH. 12:00 13:00 1.00 173 70 INTRM1 DRILL PULD T Downloaded MWD and LD same, inspected Geopilot and bit and ck'd ok. Appears to be a failure in the HCIM. 13:00 14:00 1.00 70 70 INTRM1 DRILL PULD T MU backup MWD and uploaded same. 14:00 14:30 0.50 70 449 INTRM1 DRILL TRIP T RIH from 70' to 449' 14:30 15:00 0.50 449 449 INTRM1 DRILL DHEQ T Shallow tested MWD and Geopilot. 15:00 17:00 2.00 449 4,283 INTRMI DRILL TRIP T RIH from 449' and lost dn wt at 4,128', washed down to btm at 4,283'. 17:00 00:00 7.00 4,283 4,919 INTRM1 DRILL DRLG P Directionally drilled 9 7/8" hole with Geopilot from 4,283' to 4,919' MD/ 2,709' ND (636') ADT 4.1 hrs, began to add lubricants to mud to assist in torque and drag., clean hole ECD is 9.6 ppg and with 9.0 ppg MW, ave ECD 9.8 05/07/2007 00:00 12:00 12.00 4,919 6,155 INTRM1 DRILL DDRL P Directionally drilled 9 7/8" hole with Geopilot from 4,919' to 6,155' MD/ 3,052' TVD (1,236') ADT 7.25 hrs, ave MW 9.05 ppg, ave ECD 10.0 ppg. Pumped 35 bbl wYd (2# over MU~ hi vis sweep at 5,515' and had 10% increase in cuttings back from the swee . 12:00 00:00 12.00 6,155 7,385 INTRM1 DRILL DDRL P Directionally drilled 9 7/8" hole with Geopilot from 6,155' to 7,385' MD/ 3,380' ND (1,230') ADT 7.95 hrs, ave MW 9.0 ppg, ave ECD 9.95 ppg. maintainin lubes in mud u at 2%. 05/OS/2007 00:00 00:15 0.25 7,385 7,385 INTRM1 DRILL SFTY P PJSM, Hazzard recognition while drillin 00:15 12:00 11.75 7,385 8,546 INTRM1 DRILL DDRL P Directionally drilled 9 7!8" hole with Geopilot. ADT 6.5 hrs, ave MW 9.1 ppg, ave ECD 10.14 ppg. maintaining lubes in mud up at 2%. Pumped high vis swee at 8295'. 12:00 00:00 12.00 8,546 9,148 INTRM1 DRILL DDRL P Directionally drilled 9 7/8" hole with Geopilot. ADT 6.7 hrs, ave MW 9.1 ppg, ave ECD 9.92 ppg. maintaining lubes in mud up at 2%. Dritled 5 concretions totalin 40'. 05/09/2007 00:00 00:15 0.25 9,148 9,148 INTRM1 DRILL SFTY P PJSM Hazard recognition - drilling ahead 00:15 12:00 11.75 9,148 9,966 INTRM1 DRILL DDRL P Directionally drilled 9 7/8" hole to TD. ADT 8.6 hrs, ave MW 9.1 ppg, ave ECD 10.05 ppg. maintaining lubes in mud u at 2%. 12:00 12:15 0.25 9,966 9,966 INTRM1 DRILL OWFF P Check well for flow - static 05/09/2007 12:15 19:30 7.25 9,966 4,062 INTRM1 DRILL REAM P BROOH until inside surface casing. Calculated fill 76.5 BBLS. Actual fill 81.5 BBLS 19:30 20:30 1.00 4,062 4,062 INTRM1 DRILL CIRC P Pump 35 BBL Hi viscosity sweep inside surface casing. Pumping at 605 gpm, rotating 130 rpm. 10% increase in cuttin s. 20:30 20:45 0.25 4,062 4,062 INTRM1 DRILL OWFF P Check well for flow - static. Pump dry 'ob and blow down to drive. 20:45 21:30 0.75 4,062 1,875 INTRM1 DRILL TRIP P POOH on elevators. 21:30 21:45 0.25 1,875 1,875 INTRM1 DRILL PULD P Lay down ghost reamer and DDSR sub. 21:45 22:30 0.75 1,875 357 INTRM1 DRILL TRIP P POOH on elevators. 22:30 23:30 1.00 357 357 INTRM1 DRILL TRIP P Lay down HWDP, jars and NM flex collars. Calcuated fill from shoe 35.25 BBLS. Actual fill 39.2 BBLS. 23:30 00:00 0.50 357 357 INTRM1 DRILL PULD P Download MWD 05/10/2007 00:00 00:30 0.50 125 125 INTRM1 DRILL SRVY P Con't Down Load MWD 00:30 01:30 1.00 125 125 INTRM1 DRILL PULD P UD BHA #3 per Sperry Sun 01:30 02:00 0.50 125 0 INTRM1 DRILL PULD P Wash, clean & clear all tools & Subs from ri floor 02:00 02:30 0.50 0 0 INTRM1 DRILL RURD P R/U and pull wear bushing 02:30 03:00 0.50 0 0 INTRM1 CASIN SFTY P PJSM - Discuss all know hazards and pinch points - Discuss & review casing detail 03:00 04:30 1.50 0 0 INTRM1 CASINC RURD P R/U to run 7 5/8" 29.7# L80 BTCM casin . 04:30 12:00 7.50 0 4,070 INTRM1 CASINC RNCS P Run csg per detail - 119 jts @ 5098' MD - Circu BU+ (4070') -@ 5098' Up wt 120k, Dn wt 76k - Ali has gone well - No roblems or ti ht hole 12:00 13:15 1.25 4,070 4,070 INTRM1 CASIN CIRC P Circulate Hi vis sweep surface to surface 5 b m 13:15 17:15 4.00 4,070 9,960 INTRM1 CASINC RNCS P Continue running casing to TD. Record torque & drag every 5 joints. Calculated displacement 106.25 BBLS Actual displacement 82.9 BBLS. Final PU=185 S0=85 17:15 18:15 1.00 9,960 9,960 INTRM1 CASIN( CIRC P Circulate bottoms up thru Franks fill up tool. Stage pumps to 52 spm, 220 m, 490 si. 18:15 18:45 0.50 9,960 9,960 INTRM1 CASIN RURD P Lay down Fill up tool, blow down top drive and ick u cement head. 18:45 20:45 2.00 9,960 9,963 INTRM1 CASINC CIRC P Circulate and condition mud for cement job. Rate 64 spm, 271 gpm, 575 psi. 20:45 00:00 3.25 9,945 9,945 INTRM1 CEME DISP P Cement 7-5/8" intermediate casing. Dowell pumped 10 bbls of water and pressure tested lines to 2,500 psi. Pumped 50 bbis of 8.3 ppg CW 100 and 75 bbls of 11.0 ppg mudpush. Dropped bottom piug. Mixed and pumped 222 bbls Deepcrete cement at 12.5 ppg. Shut down and dropped top plug. Reciprocating pipe and had full returns. Shoe set at 9945' MD / 3971' TVD 05/11/2007 00:00 00:45 0.75 9,945 9,945 INTRM1 CEME~ DISP P Pumped calculated strokes plus half the shoe track and did not bump the plug. Held 700 psi on floats for 5 minutes. Floats held. 00:45 01:45 1.00 0 0 INTRM1 WELCT NUND P Nipple down, pick up well head and BOP to set emergency slips. Set slips with 70k over block wei ht. 01:45 03:00 1.25 0 0 INTRM1 WELCT OTHR P Cut 7-5/8" casing with pnumatic cutter. 03:00 03:30 0.50 0 0 INTRM1 WELCT OTHR P Install 10-3/4" x 7-5/8" pack off and test to 3600 isi. Held for 10 minutes. 03:30 04:30 1.00 0 0 INTRM1 WELCT NUND P Nipple up wellhead and BOP. 04:30 05:00 0.50 0 0 INTRM1 DRILL OTHR P Install 9" ID wear ring. 05:00 07:30 2.50 0 0 INTRM1 DRILL LOT T Attempt to perform leak off test on 10-3/4" x 7-5/8" annulus using WBM. Unable to build pressure. Traced lines, checked valves and pits. Switched to rig water. (simops install mouse hole and la down 45 ~oints of 5" drill i e. 07:30 08:00 0.50 0 0 INTRM1 DRILL LOT P perform leak off test on 10-3/4" x 7-5/8" annulus using rig water. Leak off at 325 si, 11.6 08:00 14:45 6.75 0 0 INTRM1 DRILL PULD P Continue laying down 270 joints of 5" drill pipe using mouse hole. (simops freeze protect 10-3/4" x 7-5/8" annulus with 100 bbls of diesel. Pumped at 1 bpm. Initial pressure 150 psi, final ressure 850 si 14:45 15:30 0.75 0 0 INTRM1 DRILL PULD P Clear rig floor. PJSM - changing out tools to handle 4" drill i e. 15:30 20:15 4.75 0 0 INTRM1 DRILL PULD P Pick up, drift and run in hole with 123 joints of 4" drili pipe and 19 joints of h brid drill collars. 20:15 21:15 1.00 0 0 INTRM1 DRIlL PULD T Hydraulic hose on iron roughneck failed. Fabricated and re laced hose. 21:15 00:00 2.75 0 0 INTRM1 DRILL PULD P Continue pick up, drift and run in hole with 26 joints of hybrid drill collars, 21 joints HWDP and 12 joints of drill pipe with su er sliders. 05/12/2007 00:00 00:45 0.75 0 0 INTRM1 DRILL PULD P Continue to pick up 4" drill pipe with i 05/12/2007 00:45 03:30 2.75 0 0 INTRM1 DRILL TRIP P POOH racking back 11 stands of 4" drill pipe with super sliders, 7 stands of HWDP, 15 stands hybrid push pipe and 41 stands of 4" drill i e. 03:30 06:00 2.50 0 0 INTRMI DRILL PULD P Clean and clear rig floor. Change out saver sub. 06:00 07:30 1.50 0 0 INTRM1 DRILL TRIP P PU & MU BHA #4, 5200 Geopilot 07:30 08:45 1.25 0 0 INTRM1 DRILL PULD P Upload MWD 08:45 09:45 1.00 0 368 INTRM1 DRILL TRIP P Continue to MU & RIH with BHA #4. Break in eo ilot bearin s 09:45 17:00 7.25 368 9,796 INTRM1 DRILL TRIP P RIH picking up drill pipe from pipe shed, 303 'oints 17:00 17:15 0.25 9,796 9,796 INTRM1 DRILL TRIP P PJSM - review procedure for slip and cut dril~in line 17:15 19:00 1.75 9,796 9,796 INTRM1 RIGMN SVRG P Slip and cut 79' of drilling line. Service blocks and to drive. 19:00 19:30 0.50 9,796 9,855 INTRM1 DRILL TRIP P Break circulation and wash in to top of cement. Tagged cement at 9855 MD. Circulate 1 drill i e volume. 19:30 20:00 0.50 9,855 9,765 INTRM1 CASIN( OTHR P Stand back 1 stand. Rig up and test casing. Test failed. Shut in pressure 3075 psi. Lost 10% of pressure in 15 minutes. 20:00 20:45 0.75 9,765 9,765 INTRM1 CASINC CIRC T Circulate full bottoms up for retest of casin . 20:45 22:00 1.25 9,765 9,765 INTRM1 CASINC OTHR T Pressure test casing. test failed. Shut in pressure 3135. Lost 10% in 30 minutes. Circulate while called town. Decision to TOOH and RIH with test acker. 22:00 22:30 0.50 9,765 9,765 INTRM1 DRILL CIRC T Mix and pump dry job, blow down top drive. 22:30 00:00 1.50 9,765 6,903 INTRM1 DRILL TRIP T POOH with geopilot in order to run casin test acker. 05/13/2007 00:00 01:00 1.00 6,903 260 INTRM1 CASIN OTHR T Con't POOH f/ 6903' - Wet Shoe sus ected 01:00 01:45 0.75 260 94 INTRM1 CASIN OTHR T Std bk HWDP & Jars - 2 stds NMFIex DCs 01:45 0230 0.75 94 94 INTRM1 CASINC OTHR T Plug in to MWD - Check Condition 02:30 03:00 0.50 94 0 INTRM1 CASIN( OTHR T Std bk MWD - UD GeoPilot 03:00 03:30 0.50 0 305 INTRM1 CASIN( OTHR T PU BOT RP and 3 stds Hybrid 03:30 07:30 4.00 305 9,835 INTRM1 CASIN OTHR T RIH w/ BOT RP U 9835' MD 07:30 09:30 2.00 9,835 9,835 INTRM1 CASIN OTHR T Set packer - Test casing - Test to 3005 psi and tost 148 psi after 33 min. Bumped psi back up to 3002 psi - Lost 47 si after 36 min. 'Good TesY' 09:30 12:00 2.50 9,835 5,356 INTRM1 CASIN( OTHR T POOH f/ 9835' to 5356' MD 12:00 12:15 0.25 5,356 5,356 IINTRM1 CASIN( SFTY P PJSM - Discuss tripping hazards & oinch ooints ~ • 05/13/2007 12:15 14:00 1.75 5,356 0 INTRM1 CASINC OTHR T Con't POOH f/ 5356' - Std bk NMDCs - UD BOT RP - Clear ri floor 14:00 18:30 4.50 0 9,855 INTRM1 DRILL TRIP T P/U BHA #5 - Program MWD - RIH w! BHA and 4" DP. Fill pipe and test MWD @ 3166'. Continue to RIH and fill pipe at 6900'. Break circulation at 9796'. 18:30 20:30 2.00 9,855 9,986 INTRM1 CEME~ COCF P Tag at 9855'. Drill cement equipment, rat hole and 20' of new hole 20:30 20:45 0.25 9,986 9,986 INTRM1 DRILL CIRC P Circulate on bottom 20:45 21:15 0.50 9,966 9,986 INTRM1 DRILL DDRL P Drill 20' of new hole. 21:15 22:00 0.75 9,986 9,886 INTRM1 DRILL CIRC P Puli up into casing shoe and circulate bottoms up. Eastablish base line ECD of 9.6 22:00 22:30 0.50 9,886 9,886 INTRM1 DRILL RURD P RU for FIT test. Blow down top drive. 22:30 23:00 0.50 9,886 9,886 INTRM1 DRILL FIT P Perform FIT test. EMW 12.7 ppg. Blow down test e ui ment. 23:00 00:00 1.00 9,886 10,047 PROD1 DRILL DDRL P Run to bottom and drill 6-3/4" 'A' sand lateral. 05/14/2007 00:00 00:15 0.25 10,047 10,047 PROD1 DRILL SFTY P PJSM - hazard recognition, drilling ahead 00:15 12:00 11.75 10,047 11,186 PROD1 DRILL DDRL P Drilling 6-3/4" 'A' lateral. ECDs - 10.39. Drilled 3 concretions, total foota e 18'. 12:00 12:15 0.25 11,186 11,186 PROD1 DRILL SFTY P PJSM - hazard recognition, dri-ling ahead 12:15 00:00 11.75 11,186 12,060 PROD1 DRILL DDRL P Drilling 6-3/4" 'A' lateral. ECDs - 10.61. Drilled 10 concretions, total footage 72'. Pumped hi-vis sweep @ 11900. Saw 10% increase in cuttin s. 05/15/2007 00:00 00:15 025 12,060 12,060 PROD1 DRILL SFTY P PJSM - Hazard Recognition, drilling ahead. 00:15 12:00 11.75 12,060 13,143 PROD1 DRILL DDRL P Drilled 6-3/4" hole in A2 sand lateral from 12,060' to 13,143' MD / 3807' ND. ADT - 7.6 hrs, MOBM MW - 8.4 ppg, ECDs - 10.92, Max gas 77 units. Drilled 4 concretions, total foota e 46'. 12:00 12:15 0.25 13,143 13,143 PROD1 DRILL SFTY P PJSM - Hazard Recognition, drilling ahead. 12:15 00:00 11.75 13,143 14,370 PROD1 DRILL DDRL P Drilled 6-3/4" hole in A2 sand lateral from 13,143' to 14,370' MD / 3926' ND. ADT - 8 hrs, MOBM MW - 8.5 ppg, ECDs - 11.21, Max gas 93 units. Drilled 4 concretions, total footage 31'. Pumped 30 BBLS Hi-Vis sweep @ 13,200', returns 5% extra. 05/16/2007 00:00 00:15 0.25 14,370 14,370 PROD1 DRILL SFTY P PJSM - Hazard Recognition, drilling ahead. 05/16/2007 00:15 12:00 11.75 14,370 15,480 PROD1 DRILL DDRL P Drilled 6-3/4" hole in A2 sand lateral w/ GeoPilot from 14,370' to 15,480' MD / 3943' ND. ADT - 8 hrs, WOB 3-8 K, MOBM MW - 8.5 pP9 ECDs - 11.23, 140 RPM, 314 gpm @ 3700 psi Rot Wt 90 K, PU Wt 200 K Max gas 54 units, Drilled 1 concretion, total foota e 6'. 12:00 12:15 0.25 15,480 15,480 PROD1 DRILL SFTY P PJSM - Hazard Recognition drilling ahead. 12:15 14:30 2.25 15,480 15,822 PROD1 DRILL DDRL P Drilled 6-3/4" hole in A2 sand lateral w/ GeoPilot from 15,480' to 15,822' MD / 3951' ND. ADT - 2.4 hrs, WOB 4-6 K, MOBM MW - 8.4 PP9 ECDs - 1123, 140 RPM, 314 gpm @ 3850 psi Rot Wt 97 K, PU Wt 200 K Max gas 86 units, Drilied 1 concretion, total foota e 4'. 14:30 15:00 0.50 15,822 15,822 PROD1 DRILL CIRC P Circulate - Obtain Kill Rates - Monitor well static. 15:00 22:00 7.00 15,822 9,887 PROD1 DRILL REAM P BROOH from 15,822' to 9,887' @ 315 GPM, 120 RPM, 30-45 FPM. 22:00 00:00 2.00 9,887 9,887 PROD1 DRILL CIRC P Pump Hi Vis sweep around @ 319 gpm, 2750 psi, 110 RPM. Circulate & recip pipe f/ 9935' U 9887'. Sweep returned zero cuttin s. 05l17/2007 00:00 00:30 0.50 9,887 9,945 PROD1 DRILL CIRC P Continue circulating 2 BU's - 88 spm, 110 r m, 2650 si. 00:30 01:15 0.75 9,945 12,311 PROD1 DRILL TRIP P TIH from 9,945' to 12,311'. 01:15 04:15 3.00 12,311 15,200 PROD1 DRILL TRIP P RIH from12,311' to 15,200' @ 100 RPM due to loss of SO Wt - Trq 8k - Pum in 40 s m 950 si. 04:15 07:00 2.75 15,200 15,200 PROD1 DRILL CIRC P Circulate sweep & 2 BU @ 320 GPM - 3600 si - 130 r m- Tr 9K ft-Ibs. 07:00 08:30 1.50 15,200 15,200 PROD1 DRILL CIRC P Displace well to SFOBM @ same rate. PU wt 200k. 08:30 08:45 0.25 15,200 15,200 PROD1 DRILL OTHR P Flow check - Blow Dwn TD - Install air sli s- Dro Rabbit on 95' wire. 08:45 12:00 3.25 15,200 11,475 PROD1 DRILL TRIP P POOH from 15,200' to 11,475' MD on elevators. 12:00 12:15 025 11,475 11,475 PROD1 DRILL SFTY P PJSM - POOH Hazard Recognition. 12:15 16:30 4.25 11,475 95 PROD1 DRILL TRIP P Continue POOH from 11,475' - Stand back HWDP, Jars, & Flex DC's. 16:30 17:30 1.00 95 95 PROD1 DRILL OTHR P Down load MWD Data - Clean Floor - Lube Crown 17:30 18:45 1.25 95 0 PROD1 DRILL PULD P LD MWD - GeoPilot - Geo Flex - Smart STB & Bit. 18:45 19:15 0.50 0 0 COMPZ CASINC RURD P Clean & Clear Rig Floor - RU tongs & eauioment to run Liner. • i • ~ . ~ ~ ,.,.rus.v. ..::: -,< ~ ..~e+:•.~~.n ~ m~.a.r:a~.. ~ .~:c.aciE,,,, .., ..~.:.:.vc tt r,¢c 4 .,c,r~taRac..::~~ $.€uu~€C::~+ . ::~7c(ucUt'.A .•...F:~,~'y .:E:a:~:~1Ya.. . ~`-...,.:. ....Y:;t , tr,,:... • •.. «>~~;fi.d•. 05/18/200 7 21:00 00:00 3.00 0 4,965 PROD2 DRILL TRIP P RIH with Whipstock/Mill Assembly - Shailow Pulse Test @ 855' - Cont RIH U 4965 - Install Micro-Chip super slider. 05/19/2007 00:00 03:30 3.50 4,965 8,667 PROD2 DRILL TRlP P Cont R1H to 7392' MD_ Mad Pass to 7462' - Good GR Coorelation. RIH slow to 8605' MD - Break circulation and Orient the whipstock - Verify with surveys - PU Single and RIH - Sting 2.84' into PKR - Set Whipstock 17 deg Left of High Side @ 8667', PU Wt =133K&SOWt=55K. 03:30 04:00 0.50 8,667 8,667 PROD2 DRILL CIRC P Initiate circulation & dispiace well to 8.5 ppg OBM - 285 GPM - 81 SPM - ~ 2000 si. 04:00 11:30 7.50 8,667 8,712 PROD2 DRILL MILL P Mill from 8667' to 8712' with 20' of gauged hole f/ 8680' U 8700' MD. Top ~ of Window @ 8667' - Btm of Window ~..~._ . `y ~ @ 8680'. Wts = PU 135K, SO = 55K, Rot = ~ ~~- ~ ' ~t~ '~ 77K. ECD 9.97 ~ ~ ~ 11:30 12:00 0.50 8,712 8,712 PROD2 DRILL CIRC P CBU - Ream/Dress window interval clean. Pumped sweep @ 8673' with 20% increase in returns. Pumped sweep @ 8685' and 8696' w/ 5% increase on returns - Slide & pull clean. 12:00 12:15 0.25 8,712 8,712 PROD2 DRILL OTHR P PJSM - Monitor weil - Static - Pump slu & Blow Dwn. 12:15 T430 2.25 8,712 290 PROD2 DRILL TRIP P POOH with milling assemblyto 290'. 14:30 15;30 1.00 290 100 PROD2 DRILL OTHR P Flush MWD with mineral oil - Stand back Drill Coilars and download MWD. 15:30 16:30 1.00 0 0 PROD2 DRILL PULD P LD Bumper sub, MWD, & Milling Assembly - Upper Mill Full Gauge. Clear floor. 16:30 17:30 1.00 0 0 PROD2 DRILL OTHR P Pull wear ring - Flush BOP Stack 17:30 18:00 0.50 0 0 PROD2 WELCT OTHR P Set test plug & RU fortest - Fill stack & choke manifold w/ water. 18:00 18:15 0.25 0 0 FROD2 WELCT $FTY P PJSM - High Pressure hazard reco nition. 18:15 22:30 4.25 0 0 PROD2 WELCT BOPE P Tested BOPE: Tested upper pipe rams, All choke manifold vlvs, Upper & Lower IBOP, Floor Valve & Dart Valve, HCR and Manual on Choke & Kill Valves, Annular, and Blind Rams. All tests 250 psi low and 3000 psi high. Accumulator test: Mitial pressure , 3000psi - 1775 after functioning - 200 ' psi gain in 37 sec - Full recovery 2 min 50 sec. Ave N2 bottle 2200 psi. ** John Crisp with AOGCC waived witnessin af the test. 22:30 23:30 1:00 0 0 PROD2 WELCT OTHR P Puil test plug -Set Wear ring - Blow - down choke & lines. ~ . '`firrie~t;.o L7c~t ~~ ~E~?txt TE~ '- ~E~ttr ~'~~ ' ~ S: €~ t(i. ~.'~~ CIc ft't ~I7~3~ ~ '~~ Cqd~~ ~~~~ SUbC~d~ . :~ _ ? C(}~II ~ 05/19/2007 23:30 00:00 0.50 0 0 PROD2 RIGMN SVRG P CO Saver Sub. 05/20/2007 00:00 01:15 1.25 0 0 PROD2 RIGMN SVRG P PJSM - CO Saver Sub 01:15 02:30 1.25 0 0 PROD2 DRILL PUID P MU BNA #7 02:30 03:00 0.50 0 0 PROD2 DRILL OTHR P Upload MWD Data 03:00 05:30 2.50 0 0 PROD2 RIGMN RGRP T Trouble Shoot Hydraulic leak on Top Drive 05:30 06:30 1.00 0 360 PRODZ DRILL TRIP P RIH to 360' - Break in seals on GeoPilot and shallow test MWD tools. 06:30 07:15 0.75 360 360 PROD2 RIGMN RGRP T CO Saver Sub - Driller closed grabbers on threads. 07:15 11:15 4.00 360 8,712 PROD2 DRILL TRIP P Continue RIH to 8667'. PU Wt = 125K, SO Wt = 65K. Slide through window to 8699' no pump no problems. Wash & Ream to 8712' - 300 GPM - 85 SPM 2500 si - 50 RPM, Tr 5-7 K 11:15 12:00 0.75 8,712 8,731 PROD2 DRILL DDRL P Drill 6-3/4" hole w/GP f/8712' U 8731' MD 3691' ND. Wts = PU 125K SO 65K Rot 75K, Tq On btm 6-7K ECD 9.82 ppg - Jar Hrs 135.04 - Concretion 8730-8731' 12:00 12:15 0.25 8,731 8,731 PROD2 DRILL SFTY P PJSM - Drilling ahead hazard reco nition 12:15 16:45 4.50 8,731 8,827 PROD2 DRILL DDRL P Drill 6-3/4" hole w/GP f/ 8731' U8827' MD 3696' ND Wts = PU 135K SO 56K Rot 80K, Tq On btm 6-7K ECD 9.77 ppg - Jar Hrs 138.24 - MaxGas 56 Un+ts Drilled Concretions @ 8731-8734, 8780-8804, 8810-8818, 8826-8827', Total of 37'. 16:45 18:00 125 8,827 8,827 PROD2 DRILL CIRC T Circulate & Trouble Shoot MWD tools - Pulser stopped working - Check Kill Rates - Monitor Well & Pump Slug - Blow Down TD. 18:00 20:30 2.50 8,827 0 PROD2 DRILL TRIP T Decision made to TOOH for new pulser - POOH f/ 8827' MD - Stand back HWDP, Jars, Flex DCs, STB & Float Sub. (Displacement 5 BBLS lon 20:30 21:30 1.00 0 0 PROD2 DRILL PULD T Download & Check MWD 21:30 22:00 0.50 0 0 PROD2 DRILL PULD T Pull Pulser - LD TM, DGR, EWR, PWD - Check GP & Grade Bit Good. 22:00 22:15 0.25 0 0 PROD2 RIGMN SVRG P Service TD & Blocks 22:15 22:45 0.50 0 0 PROD2 DRILL PULD T CO & PU DGR, EWR, PWD, and TM - PU Stab & Float sub. 22:45 00:00 1.25 0 0 PROD2 DRILL OTHR T Program MWD - DM Connection Fault - CO Connector Ti . Page 14 of 34 ' • ~ ~m~~ °~ '~ ~ at~ . '~~~ ~ Frc~rii ~ 3 '~o :- ; . ~u~-~; ~: [~e ~ tti ° ~ ~ th Phas~~ %~? ~Coei~~. ' = Subecs~e - ~' ~~'~ ~OM ~` 05/21/2007 00:00 01:00 1.00 88 458 PROD2 DRILL PULD T PJSM - Continue MU BHA - Upload MWD - MU NMF DC's - HWDP & Jars RIH 1 Stand U 458' MD for Shallow Pulse Test - 300 GPM - 85 SPM @ 1300 si. 01:00 04:15 3.25 458 8,827 PROD2 DRILL TRIP T RIH U 8769' and slide through window no problems. Wash & Ream to 8827' - 310 GPM - 87 SPM @ 2500 psi. Rot Wt 50 r m- Tr 5-7K. 04:15 12:00 7.75 8,827 8,988 PROD2 DRILL DDRL P Drill 6-3/4" hole w/GP f/ 8827' U 8988' MD 3703' TVD Wts = PU 125K SO 60K Rot 80K, Tq On/Off btm 7/ 7K, ECD 9.78 ppg Drilled Concretions 8826-8844, 8852-8858, 8917-8923, 8931-8944, 8984-8988, Total of 47'. 12:00 00:00 12.00 8,988 9,546 PROD2 DRILL DDRL P Drill 6-3/4" hole w/GP f/ 8988' U 9546' MD 3706' ND Wts = PU 135K SO 55K Rot 80K, Tq On/Off btm 6.5/7 K, ECD 10.4 ppg Drilled Concretions 8988-8994, 9012-9019, 9023-9035, 9095-9096, 9103-9120, 9133-9142, 9144-9157, 9172-9178, 9180-9185, 9242-9245, Total of 79'. 05/22/2007 00:00 08:45 8.75 9,546 9,974 PROD2 DRILL DDRL P Directional drill "B" lateral. Max Gas 71 Units Note: 11 Concretions drilled = 55'. De th's noted on Geolo ist re ort. 08:45 12:00 3.25 9,974 9,974 PROD2 DRILL REAM NP Ream and dress 17 deg dogleg from 9954' to 9974'. Dressed down to a finai of 14 de . 12:00 00:00 12.00 9,974 10,593 PROD2 DRILL DDRL P Directional drill "B" lateral. Max Gas 145 Units Note: 13 Concretions drilled = 91'. De th's noted on Geolo ist re ort. 05/23/2007 00:00 11:45 11.75 10,593 11,385 PROD2 DRILL DDRL P Directional drill "B" lateral. Max Gas 80 Units Note: 8 Concretions drilled = 48'. De th's noted on Geolo ist re ort. 11:45 12:00 0.25 11,385 11,393 PROD2 DRILL DDRL P Directional drill "B" lateral. Max Gas 80 Units 12:00 15:45 3.75 11,393 11,618 PROD2 DRILL DDRL P Directional driil "B" lateral. Max Gas 80 Units. Pumped a 30 bbls Hi vis sweep while drilling @ 11480'. Only a 5% increase in cuttings when returned. Note: 5 Concretions drilled = 62'. Depth's noted on Geologist report. Decision was made to POOH and sidetrack due to a 20.21 deg dogleg in 21' after drilling a 16' concretion from 11531' to 11587'. 15:45 16:30 0.75 11,618 11,380 PROD2 DRILL TRIP NP Pull out of the hole for open hole sidetrack 11385'. 16:30 1930 3.00 11,380 11,415 PROD2 DRILL DDRL NP Trough for open hole sidetrack @ 11385'. Page 15 af 34 ! ~ Tme L' D te ,'' Frotcn n To .' ' Dur S. De th` E:: De th Phase ; Ct~cfe ' Su6cac.fe T: C~UI 05/23/2007 19:30 20:00 0.50 11,415 11,435 PROD2 DRILL DDRL NP Control drill. Work through open hole sidetrack. OK. 20:00 22:30 2.50 11,435 11,603 PROD2 DRILL DDRL NP Directional drill "B" lateral. Max Gas 80 Units Note: 8 Concretions drilled = 48'. De th's noted on Geolo ist re ort. 22:30 22:45 0.25 11,603 11,603 PROD2 DRILL CIRC T Circulate while trying to get Sperry Sun MWD com uters to work. 22:45 23:00 0.25 11,603 11,569 PROD2 DRILL TRIP T POOH one stand while diognose MWD com uters. 23:00 00:00 1.00 11,569 11,569 PROD2 DRILL CIRC T Trouble shooting Computers in Sperry Sun house. Circulate while reciprocate pipe f/ 11569' to 11475'. Note: Final diagnose is that a hardware card is bad. (Data Scan card). This card was causing the processsor to lock up, this card athers data such as tor ue and r m. 05/24/2007 00:00 00:3Q 0.50 11,569 11,603 PROD2 DRILL CIRC T MAD pass from 11565' to 11603' Note: Final diagnose of Sperry Sun computer problem is that a hardware card is bad. (Data Scan card). This card was causing the processsor to lock up, this card gathers data such as tor ue and r m. 00:30 00:45 0.25 11,603 11,618 PROD2 DRILL DDRL NP Directional drill "B" lateral. Max Gas 80 Units 00:45 03:45 3.00 11,618 11,890 PROD2 DRILL DDRL P Directional drill "B" lateral. Max Gas 70 Units Note: 1 Concretions drilled = 4'. De th's noted on Geolo ist re ort. 03:45 07:15 3.50 11,890 11,974 PROD2 DRILL DDRL P Directional drill "B" lateral. Max Gas 70 Units Note: 1 Concretions drilled = 4'. De th's noted on Geolo ist re ort. 07:15 07:45 0.50 11,974 11,890 PROD2 DRILL TRIP T Decision to POOH to sidetrack well. POOH for sidetrack. 07:45 0830 0.75 11,890 11,920 PROD2 DRILL DDRL T Trough for open hole sidetrack. 08:30 09:00 0.50 11,920 11,920 PROD2 DRILL CIRC T Reboot Sperry Sun MWD computers. Circulate and reciprocate from 11890' to 11920'. 09:00 09:45 0.75 11,920 11,920 PROD2 DRILL REAM T Continue to trough for open hole sidetrack. 09:45 10:30 0.75 11,920 11,974 PROD2 DRILL DDRL T Directional drill "B" lateral. Max Gas 70 Units Note: no Concretions drilled = 0'. 10:30 12:00 1.50 11,974 12,053 PROD2 DRILL DDRL P Directional driil "B" lateral. Max Gas 70 Units Note: 1 Concretions driiled = Starts @ 12052'. Depth's noted on Geologist re ort. 12:00 20:45 8.75 12,053 12,594 PROD2 DRILL DDRL P Directional drill "B" lateral. Max Gas 85 Units Note: 8 Concretions drilled = 65'. De th's noted on Geolo ist re ort. Page 18 0€ 34 '' ~ ~ Time L ` Llafe firc~m To ~ur ': 5: De th E.'; De~ th Fhase '. Code ;`' Subeode T: CCC:~MM 's 05/24/2007 20:45 22:45 2.00 12,594 12,800 PROD2 DRILL DDRL P Directional drill "B" lateral. Max Gas 85 Units Note: 2 Concretions dril(ed =2'. De th's noted on Geolo ist re ort. 22:45 00:00 1.25 12,800 12,904 PROD2 DRILL DDRL P Directional drill "B" lateral. Max Gas 85 Units Note: no Concretions drilled = 0'. 05/25/2007 00:00 01:00 1.00 12,904 12,964 PROD2 DRILL DDRL P Directional drill "B" lateral. Max Gas 87 Units. TVD 3765'. Note: no Concretions drilled = 0'. 01:00 01:30 0.50 12,964 12,800 PROD2 DRILL TRIP T Decision to POOH and sidetrack. Out the to of the "B" lateral 01:30 02:30 1.00 12,800 12,830 PROD2 DRILL REAM T Trough forsidetrack. 02:30 05:00 2.50 12,830 12,964 PROD2 DRILL DDRL T Directionat drill "B" lateral. Max Gas 85 Units Note: no Concretions drilled. 05:00 12:00 7.00 12,964 13,125 PROD2 DRILL DDRL P Directional drill "B" lateral. Max Gas 94 Units Note: 4 Concretions drilled = 40'. De th's noted on Geolo ist re ort. 12:00 18:30 6.50 13,125 13,207 PROD2 DRILL DDRL P Directional drill "B" lateral. Max Gas 64 Units Note: 5 Concretions drilled = 31'. De th's noted on Geolo ist re ort. 1830 19:00 0.50 13,207 13,207 PROD2 DRILL OWFF T Survey, monitor well- OK, install stri er rubbers. 19:00 19:45 0.75 13,207 12,594 PROD2 DRILL REAM T Backream out of the hole. Note: Pulled top super slider with microchip (stand # 112}. Repiaced su er slider. 19:45 00:00 425 12,594 10,170 PROD2 DRILL REAM T Backream out of the hole. Note: Pulled top super slider with microchip (stand # 112). Replaced su er slider. 05/26/2007 00:00 01:00 1.00 10,170 8,863 PROD2 DRILL REAM T Backream out of the hole. Pumping 310 gpm, rotating 120 rpm. PU wt 125k, SO wt 65k. 01:00 01:15 0.25 8,863 8,584 PROD2 DRILL TRIP T Pull out of hole to above window. window to -8667' 01:15 01:30 0.25 8,584 8,584 PROD2 DRILL OWFF T Monitorwell, OK. 01:30 03:00 1.50 8,584 8,584 PROD2 DRILL CIRC T Pump a 30 bbl Hi vis weighted sweep (10.5 ppg/ 200+ vis). Pump surface to surface + a bottom's up. Total of 7400 strokes. 10% increase in cuttings. Rotate 100 rpm w/ 6k ft Ib torque, reciprocate 60' length. Pumping 310 m w/ 2200 si. 03:00 03:15 0.25 8,584 8,584 PROD2 DRILL OWFF T Monitor well, OK. Pump a dry job. 03:15 05:45 2.50 8,584 221 PROD2 DRILL TRIP T Pull out of the hole on elevators. Monitor well on tri tank. Page 17 af 34 ' ~ ~ rm~ Lo: €~ate From To: ' Clur '. ~. De" t!~ E.'De th Phase ' Gaiie Subcoife T : OM ` 05/26/2007 05:45 06:00 0.25 221 221 PROD2 DRILL PULD T Lay down a single 4" HWDP, UD jars (hours) (ser # 14001295), MU new set of jars (ser # 14471015), MU single HWDP. Rack back stand in the derrick. 06:00 06:15 0.25 221 94 PROD2 DRILL TRIP T Stand back a stand of 4 3/4" flex collars. 06:15 06:30 0.25 94 87 PRQD2 DRILL PULD T Lay down welded blade stabilizer and float sub. 06:30 07:00 0.50 87 0 PROD2 DRIIL OTHR T PU and observe that the bit (Security 6 3/4" FMF3641Z, ser # 10968969) is missing and 1.06' of the Sperry Sun 5200 geopilot (Ser # TL015) was left in the hole. Total length IeR in the hole = 2.34'. 07:00 08:00 1.00 0 77 PROD2 DRILL OTHR T RIH, Download Sperry Sun MWD. 08:00 08:30 0.50 77 0 PROD2 DRILL PULD T Lay down BHA: Sperry Sun TM, MWD, DM, SMT, stabilizer, geo-pilot flex 'oint, and the eo ilot TL 015 . 08:30 09:00 0.50 0 0 PROD2 DRILL OTHR T Cfean and clear rig floor. 09:00 10:15 1.25 0 85 PROD2 DRILL PULD T PU/MU BHA # 9. Picked up a rebuilt Security 6-3/4" (FMF3641Z, ser # 1091692) bit, another Sperry Sun 5200 series GeoPilot (ser # TL041), a new geo Flex collar (ser # 828261), and a new S er sun TM ser # 97552). 10:15 11:30 1.25 85 85 PROD2 DRILL OTHR T Upload MWD. Recheck DM connection. Continue to u load MWD. 11:30 12:00 0.50 85 85 PROD2 DRILL OTHR T Inspect worn hardband on Sperry Sun DGR, EWR, PWD tool ser # 130905) 12:00 12:30 0.50 85 85 PROD2 DRILL PULD T Change Sperry Sun DGR, EWR,PWD (install ser # 90138305) 12:30 13:00 0.50 85 85 PROD2 DRILL OTHR T Upload Sperry Sun MWD tools. 13:00 13:30 0.50 85 463 PROD2 DRILL TRIP T Finish MU BHA #9, RIH. 13:30 13:45 0.25 463 463 PROD2 DRILL OTHR T Shallow test MWD tools and Geo-Pilot. OK. 13:45 16:15 2.50 463 8,580 PROD2 DRILL TRIP T RIH, filling drill pipe every 20 stands. 16:15 16:30 025 8,580 8,580 PROD2 RIGMN OTHR P inspect saver sub on the Varco TDS-11 to drive. 16:30 17:30 1.00 8,580 8,580 PROD2 RIGMN SVRG P Slip and cut 70' of 1-1/4" drilling line. 17:30 18:30 1.00 8,580 8,580 PROD2 RIGMN SVRG P Service Rig. 18:30 20:45 225 8,580 10,633 PROD2 DRILL TRIP T Trip in the hole. Fill pipe @ 10265'. No problems. Ran out of down weight @ 10633' stand # 110 in the hole . 20:45 22:00 1.25 10,633 11,660 PROD2 DRILL REAM T Ream in the hole because of no down wt. Pumping 242 gpm w/ 2000 psi. Rotate 50 rpm w/ 7-9k ft Ib torque. Now ast 1J-120P61. No roblems. Page '18 oF 34 : ! ~- Time La s Date Frorrt To Dur ' S. De th- E. De th Phas~ Code Subcode T' C~M : 05/26/2007 22:00 22:30 0.50 11,660 12,031 PROD2 DRIIL REAM T Ream in the hole because of no down wt. Pumping 242 gpm w/ 2000 psi. Rotate 50 rpm w! 7-9k ft Ib torque. Now ast 1J-120P62. No roblems. 22:30 23:30 1.00 12,031 12,594 PROD2 DRILL REAM T Ream in the hole because of no down wt. Pumping 242 gpm w/ 2000 psi. Rotate 50 rpm w/ 7-9k ft Ib torque. No robiems. 23:30 23:45 0.25 12,594 12,700 PROD2 DRILL REAM T Ream in the hole because of no down wt. Pumping 242 gpm w/ 2000 psi. Rotate 50 rpm w/ 7-9k ft Ib torque. No roblems. 23:45 00:00 0.25 12,700 12,594 PROD2 DRILL TRIP T POOH to trough and sidetrack hole @ 12594'. Note: Fish (bit and bit box of geopilot) did not present a problem to this de th. 05/27/2007 00:00 04:15 4.25 12,594 12,625 PROD2 DRILL DDRL T Cut trough from 12,594' to 12,625'. Rotating hours = 1.4. 140 rpm, torque = 7k ft-Ibs, Rotating weight = 72 k. SPP = 3000 si 04:15 12:00 7.75 12,625 12,870 PROD2 DRILL DDRL T Drill from from 12,625' to 12,870' TVD = 3772' ART = 4.4 hrs Note: 6 Concretions drilled = 52'. 12:00 13:45 1.75 12,870 13,207 PROD2 DRILL DDRL T Directional drill "B" lateral. Max Gas 79Units. Note: 1 Concretions drilled = 20'. 13:45 00:00 10.25 13,207 13,751 PROD2 DRILL DDRL P Directional drill "B" lateral. Max Gas 82 Units. TVD= 3768'. Note: 15 Concretions drilled = 108'. 05/28/2007 00:00 12:00 12.00 13,751 14,902 PROD2 DRILL DDRL P Directional drill "B" lateral. Max Gas 98 Units. TVD= 3785'. Note: 7 Concretions drilled = 51'. 12:00 14:00 2.00 14,902 15,266 PROD2 DR-LL DDRL P Directional drill "B" lateral. Max Gas 69 Units. ND= 3785'. Note: no Concretions drilled = 0'. 14:00 14:45 0.75 15,266 15,266 PROD2 DRILL CIRC P Circulate 35 bbl hi vis sweep out of the hole. Circ @ 310 gpm w/3550 psi. Noticed a 20% increase in cuttings when returned to surface. 14:45 22:30 7.75 15,266 16,029 PROD2 DRILL DDRL P Directional drill "B" laterai. Max Gas 74 Units. TVD= 3805'. Note: 7 Concretions drilled = 36'. 22:30 22:45 0.25 16,029 16,026 PROD2 DRILL SRVY P Obtain MWD survey. 22:45 23:00 0.25 16,026 16,026 PROD2 DRILL OWFF P Monitor well. Record SPR's. 23:00 00:00 1.00 16,026 15,715 PROD2 DRILL REAM P Backream out of the hole. Pumping @ 310 gpm. Rotating 140 rpm w/ 11 k ft ib tor ue. 05/29/2007 00:00 04:00 4.00 15,715 12,500 PROD2 DRILL REAM P Cont. to BROOH from 15,715' to 12,500', BROOH with no probiems at 310 gpm, 3,400 psi, 140 rpm's with 9-10K ft-Ibs tor ue. Page ~t9 of 3~ • ~ ' Tme La :Date From T~ '; Dur ~. EE~e th E. De th Fhas~ ' Code ; Subcode T' GOM 05/29/2007 04:00 04:30 0.50 12,500 12,034 PROD2 DRILL TRIP P Monitored weil -static, POOH on elevators from 12,500' to 12,034' and hole didn't take proper fill, st wt up 150K, dn wt -0-. 04:30 06:30 2.00 12,034 10,635 PROD2 DRILL REAM P Cont to BROOH from 12,034' to 10,635', st wt u 140K, dn wt 55K. 06:30 08:00 1.50 10,635 8,581 PROD2 DRILL TRIP P POOH on elevators from 10,635' to 8,581', no probiems pulling thru window. 08:00 10:15 2.25 8,581 8,581 PROD2 DRILL CIRC P Pumped 30 bbl hi vis sweep and circ hole clean above window, had 10% increase in cuttings back from the sweep and circ 2 additional btms up and was clean at the shakers, circ at 310 gpm, 2,300 psi, 100 rpm's with 6,500 ft-Ibs tor ue. 10:15 10:30 0.25 8,581 8,581 PROD2 RIGMN SVRG P Serviced top drive 10:30 13:00 2.50 8,581 12,407 PROD2 DRILL TRIP P RIH from 8,581' and lost down wt at 12,407'. 13:00 17:30 4.50 12,407 16,029 PROD2 DRILL REAM P Washed and reamed from 12,407' to btm at 16,029', washed down at 161 m, 1,050 si at 100 r m's. 17:30 19:30 2.00 16,029 16,029 PROD2 DRILL CIRC P Pumped 30 bbl hi vis sweep and circ out of hole, had 15% increase in cuttings back from the sweep, circ at 290 gpm, 3,900 psi, 140 rpm's, 8K ft-Ibs torque with 10.67 ppg ECD, held PJSM with ASRC vac truck drivers, st wt u 175K. 1930 21:15 1.75 16,029 16,029 PROD2 DRILL CIRC P Displaced hole over from 8.5 ppg M08M to 8.5 ppg SFMOBM, circ at 285 gpm, 3,900 psi, 140 rpm's with 10-12K ft-Ibs torque and 11.19 ppg ECD, st wt u 240K. 21:15 21:30 0.25 16,029 16,029 PROD2 DRILL OWFF P Monitored well- static, dropped 1 13/16" rabbit on wire. 21:30 23:15 1.75 16,029 13,899 PR002 DRILL TRIP P POOH on elevators from 16,029' to 13,899' and hole wasn't taking proper fill. 23:15 00:00 0.75 13,899 13,619 PROD2 DRILL TRIP P Monitored well-static, pumped out 1 std from 13,899' to 13,806' and cont to POOH on elevators to 13,619'. 05/30/2007 00:00 00:30 0.50 13,619 12,220 PROD2 DRILL TRIP P Cont. to POOH on elevators from 13,619' to 12,220' when 20K add. drag was observed and hole stopped taking calc fill. 00:30 02:30 2.00 12,220 10,914 PROD2 DRILL REAM P BROOH from 12,220' to 10,914', BROOH at 200 gpm, 1,450 psi, 50 rpm's with 10-12K ft-Ibs torque, ck'd well at 11,941' and still had slight swabbin . 0230 04:00 1.50 10,914 8,619 PROD2 DRILL TRIP P POOH on elevators from 10,914' to 8,619', no problems pulling thru window and hole took calc. fill, st wt u 145K, dn wt 37K Page 20 of 34 • ~ :Tirne Lo ~IIate ~ Frorrr Tc~ ~' ~eie ~~ S. De Ch ~~.~'~~ De #h Fh~s~ ~ Code '~~~ Sulscode T~~ GOM ;~ 05/30/2007 04:00 04:15 0.25 8,619 8,619 PROD2 DRILL OWFF P Monitored well above window and well was static. 04:15 08:15 4.00 8,619 80 PROD2 DRILL TRIP P POOH from 8,619', stood back HWDP, jars and NMFDC's POOH to 80'. 08:15 10:00 1.75 80 0 PROD2 DRILL PULD P Downloaded MWD then fin. LD BHA #9, cleared rig floor. Calc fill on trip out of hole 102 bbls, actual fill 96 bbis. 10:00 10:45 0.75 0 0 COMPZ CASIN( RURD P RU to run 4 1/2" liner 10:45 11:00 0.25 0 0 COMPZ CASIN( SFTY P Held PJSM with rig crew, tong operator and Baker rep on liner detail and associated hazards with running of the liner. 11:00 17:00 6.00 0 7,070 COMPZ CASINC RNCS P PU and RIH with 4 1/2" slotted and blank liner per well plan to 7,070', ran 151 jts of siotted and 17 jts of blanks (168 total) used both BTC and Hydril conn's. with 62 torque rings, ran 166 hydraform centralizers floating with no sto rin s. 17:00 18:00 1.00 7,070 7,145 COMPZ CASINC RNCS P MU Baker liner receptacle jt with setting sleeve RIH to 7,145', st wt up 80K, dn wt 56K, rotated at 20 rpm's with 2,500 ft-Ibs tor ue and 67K rot wt. 18:00 20:15 2.25 7,145 11,345 COMPZ CASIN( RUNL P RIH with 4 1/2" liner on 4" DP from 7,145' and lost ali down wt at 11,345' 20:15 00:00 3.75 11,345 13,399 COMPZ CASINC RUNL P Rotated liner in the hole from 11,345' to 13,399', rotated at 20 rpm's with torque limiter set at 8K ft-Ibs, st wt up 135K, rotating wt while slacking off 40-70K. 05/31l2007 00:00 03:30 3.50 13,399 16,016 COMPZ CASINC RUNL P Cont to rotate liner in the hole from 13,399', tagged btm at 16,029', PU to 16,016' liner setting depth, st up wt 163K, rot wt dn 85-95K, liner dn wt with no rotation 66K. rotated at 30 r m's with 11.5K ft-Ibs tor ue. 03:30 04:00 0.50 16,016 16,029 COMPZ CASIN( OTHR P Dropped 29/32" ball and pumped down to seat, pressured up to 3,000 psi to release running tool, then pressured up to 4,200 psi and blew the ball seat, PU from liner and was not released from liner, had same up and down wYs and was able to push liner to btm w/no roation to 16,029' 04:00 04:45 0.75 16,029 8,893 COMPZ CASINC OTHR P Dropped 1 3/4" ball and pumped down to seat, pressured up to 3,500 psi to release running tool, PU and was released from liner, st wt up 153K, dn wt 70K 04:45 09:00 425 8,893 32 COMPZ CASIN( RUNL P POOH wet from 8893' to Baker runnin tool at 32'. 09:00 10:00 1.00 32 0 COMPZ CASINC RUNL P LD Baker running tool and cleared rig floor. 1Q:00 11:00 1.00 0 334 COMPZ FISH PULD P Held PJSM then MU Baker retrieving hook on BHA #10 RIH to 334' Page 21 ofi 34 ' • ~ Tim~ L ' s 4~ate Fram To '' . Dur S. De tt~ E. th Phase ' Gode 5ub otle F'" CC~N[ :. 05/31/2007 11:00 14:30 3.50 334 8,594 COMPZ FISH TRIP P RIH with BHA #10 from 334' to 8,594' 14:30 15:15 0.75 8,594 8,681 COMPZ FISH FISH P Est. circ at 150 gpm, 700 psi, st wt up 150K, dn wt 70K, RIH from 8,594' and washed down across WS slide to 8,684' PU and worked hook latching WS at 8,681', worked st wt up to T30K over and after jarring a total of 6X WS ulled free. 15:15 15:30 025 8,681 8,500 COMPZ FISH TRIP P POOH from 8,681' to 8,500', had 10-14K add. drag and hole took an add. 1 bbl to fill hole. 15:30 15:45 0.25 8,500 8,500 COMPZ FISH OTHR P Monitored well-static 15:45 20:30 4.75 8,500 150 COMPZ FISH TRIP P POOH from 8,500' to 150', stood back 3 stds of h brid ush i e. 20:30 22:30 2.00 150 0 COMPZ FISH PULD P POOH from 150' LD bumper and oil jars, WS slide and seal assembly, cleared ri floor 22:30 23:45 1.25 0 0 COMPZ CASIN( RURD P RU to run Hook Hanger assembly. 23:45 00:00 025 0 0 COMPZ CASINC SFTY P Held PJSM on PU and MU Hook Han er with slim hole MWD. 06/01/2007 00:00 02:15 2.25 0 293 COMPZ CASIN( PUTB P MU "B" lat. Hook Hanger assembly with ECP packer and slim hole MWD RIH to 293'. 02:15 02:30 0.25 293 386 COMPZ CASINC DHEQ P RIH 1 std from 293' to 386' and shaliow tested MWD and ck'd ok. 02:30 07:00 4.50 386 8,658 COMPZ CASINC RUNL P RIH from 386' to 8,658', st wt up 150K, dn w# 70K. 07:00 09:15 2.25 8,655 8,955 COMPZ CASIN( RUNL P RIH from 8,658' and went into "B" lat on 1 st attempt, , RIH tagging liner XO at 8,959', PU and oriented HH to 10 deg rt of high side and hooked hanger, unhooked hanger and tagged back up on XO, rehooked hanger and re-confirmed hook was positioned ro erl . 09:15 10:00 0.75 8,955 8,670 COMPZ CASINC OTHR P Dropped 29/32" ball and pumped down to seat, pressured up and opened valve to ECP, inflated ECP with .3 bbl, pressured up to 3,700 psi to release running tool. Had to work st wt up to 35K over to pull running tool free, slacked off onto HH and reconfirmed HH depth and ck'd ok. Set top of HH at 8,670' with mule shoe spaced out at 4.7' from XO at 8,955'. 10:00 1030 0.50 8,670 8,476 COMPZ CASINC RUNL P POOH from 8,670' to 8,476', had 10-14K dra . 10:30 10:45 0.25 8,476 8,476 COMPZ CASIN( OTHR P Monitored well-static. 10:45 15:00 4.25 8,476 210 COMPZ CASINC RUNL P POOH from 8,476' to Baker running tool at 210'. 15:00 16:45 1.75 210 0 COMPZ CASIN< PUTB P POOH LD Baker running tool and slim hole MWD, cleared ri fioor. Page 22 0€ 34 ~ ~ Tme La D~t~ Frorn Tn ' nur ; S. De th E.:De th Ph~se Code Subeacie T CQM ' 06/01/2007 16:45 17:15 0.50 0 0 COMPZ CASINC RURD P RU handling tools and tongs to run LEM. 17:15 17:30 0.25 0 0 COMPZ CASINC SFTY P Held PJSM on MU LEM and associated hazards. 17:30 19:45 2.25 0 460 COMPZ CASIN( PUTB P MU "B" lat LEM with ZXP packer and siim hole MWD RIH to 460' 19:45 20:00 0.25 460 554 COMPZ CASINC DHEQ P RIH 1 std to 554' and shallow tested MWD at 125 gpm at 625 psi and ck'd ok. 20:00 00:00 4.00 554 8,645 COMPZ CASINC RUNL P RIH with LEM from 554' to 8,645', st wt u 140K, dn wt 70K 06/02/2007 00:00 01:15 1.25 8,645 8,816 COMPZ CASINC RUNL P Cont. RIH with LEM from 8,645', st wt up 140K, dn wt 70K, went thru top of hook at 8,670' w/no probiems, cont. RIH and oriented LEM to 26 left, RIH and saw seals go thru top of CSR, re-ck'd orientation and was at 14L then snapped into lEM on depth, set 2K st wt dn ck'd orientaion and had 5L, snapped out and snapped back in, still showed to be at 5L, good indication LEM was in position, set 35K wt down on LEM (hook run showed to be at 10R . 01:15 01:45 0.50 8,816 8,370 COMPZ CASINC OTHR P Dropped 1 3/4" ball and pumped down to seat, pressured up to 3,000 psi to seat packer then pressured up to 4,000 psi to release running tool, PU and was released from LEM. Set top of "B" lat ZXP pkr at 8,370' with mule shoe at 8,815.5'. 01:45 02:00 0.25 8,370 8,370 COMPZ CASINC DHEQ P Tested ZXP pkr and csg to 2,500 psi for 5 min, charted same, ood test. 02:00 02:15 0.25 8,370 8,370 COMPZ CASIN( OTHR P PU out of pkr, st wt up 165K and monitored well-static, blew down top drive. 02:15 03:45 1.50 8,370 4,574 COMPZ CASIN( RUNL P POOH from 8,370' to 4,574' 03:45 09:30 5.75 4,574 374 COMPZ CASIN( RUNL P Cont to POOH from 4,574' to BHA at 374', repositioned WWf supersliders while POON 45 stds - 9/'t . 09:30 10:00 0.50 374 374 COMPZ CASIN( RURD P RU tongs to l.D slim hole MWD and runnin tool. 10:00 11:00 1.00 374 0 COMPZ CASIN( PUTB P POOH making service breaks on slim hole MWD for servicing and LD Baker runnin tool, cleared ri floor. 11:00 11:30 0.50 0 0 COMPZ CASIN< OTHR P Pulled wear bushing. Pags', 23 af 34 ! • 06/02/200 7 11:30 ]6:00 4.50 0 0 COMPZ WELC T BOPE P RU and tested BOPE, tested rams, manifold and valves to 250 psi low and 3,000 psi high including annular, tested with 4" and 4 1/2" test jts, perFormed Koomey test, starting press. 3,000 psi, after functioning rams 1,700 psi, took 38 seconds to build 200 psi and 3 min 1 second for full recovery. 5 nitrogen bottles ave 2,200 psi. NOTE: Chuck Scheve with AOGCC waived witnessin of the test. 16:00 16:30 0.50 0 0 COMPZ STK OTHR P Insta(led wear bushing. 16:30 16:45 0.25 0 0 PROD3 STK OTHR P Held PJSM with Baker rep and Sperry Sun on MU of whipstock assernbly with MWD. 16:45 20:00 3.25 0 512 PROD3 STK PULD P MU "D" sand whipstock seals and milling assembly along with MWD, oriented and upioaded same, then RIH with BHA #11 to 512'. 20:00 20:15 Q.25 512 606 PROD3 STK OTHR P RIH 1 std to 606' and shallow tested MWD and ck'd ok. 20:15 00:00 3.75 606 6,207 PROD3 STK TRIP P RIH whipstock from 606' to 6,207'. 16/03/2007 00:00 00:30 0.50 6,207 7,401 PROD3 STK TRIP P RIH with whipstock from 6,207' to 7,401'. 00:30 01:00 0.50 7,401 7,478 PROD3 STK OTHR P Made MADD pass across K-13 sand f~om 7,401' to 7,478' 01:00 01:15 0.25 7,478 8,338 PROD3 STK TRIP P RIH from 7,478' to 8,338' 01:15 02:00 0.75 8,338 8,370 PROD3 STK TRIP P Est circ at 275 gpm at 2,450 psi, st wt up 138K, dn wt 70K, RIH and oriented WS to 17 deg. left of high side then set WS by tagged up on "B" lat ZXP pkr at 8,370' and sheared off from same. 02:00 02:15 0.25 8,370 8,239 PROD3 STK CIRC P Began to displace hole over from SFMOBM to 8.5 ppg MOBM, pumped mud to above WS milis. 02:15 07:00 4.75 8,239 8,281 PROD3 STK WPST P Miiled window in "D" sand lateral from 8,239' to 8,252' (13') then milled ' ~, ~~~~ ~~ - ° formation from 8,252`to 8,281' I~aving ~~ 20' of gauged hole outside of the - E~~ -- ;, ~ ~ window. Milled at 2-6K WOM, 70-90 rpm's, 4-6K ft-Ibs torque, 300 gpm at 2,600 si. 07:00 08:00 1.00 8,281 8,207 PROD3 STK CIRC P Pumped 30 bbl wYd hi vis sweep and circ hole clean while working mills thru the window, circ at 300 gpm, 2,600 psi at 100 r m's with 5-7K ft-Ibs tor ue. 08:00 08:15 0.25 8,207 8,207 PROD3 STK OTHR P Monitored well-static, biew down top drive. 08:15 09:15 1.00 8,207 4,676 PROD3 STK TRIP P POOH from 8,207' to 4,676' 09:15 09:30 0.25 4,676 4,676 PROD3 STK OTHR P Held BOP kick while tripping drill with rig crew then held post drill discussion with the crew. ~ ~ 'Time Lo s : [?~f~ " :~raFn Td ' ~ur : S. €7e th E; E'~ tt~ Fhasi ' Gade ' Subcasie T' CQiut .'. 06/03/2007 09:30 11:30 2.00 4,676 99 PROD3 STK TRIP P POOH from 4,676' to BHA at 99'. 11:30 12:30 1.00 99 0 PROD3 STK PULD P Downloaded MWD and LD miliing assembly, upper mill in gauge and cleared ri floor. 12:30 13:30 1.00 0 0 PROD3 STK OTHR P Puiled wear bushing and flushed out BOP stack, re-installed wear bushin . 13:30 13:45 0.25 0 0 PROD3 RIGMN SFTY P Held PJSM on slipping on new spool of drl line. 13:45 16:30 2.75 0 0 PROD3 RIGMN SVRG P Slipped on 1,500' of drlg line from new s ool. 16:30 18:15 1.75 0 370 PROD3 DRILL PUID P MU Geopilot BHA #12 RIH to 370, MU 6 3/4" bit #5 rr2 on Geopilot, MWD and u loaded same. 18:15 18:45 0.50 370 463 PROD3 DRILL TRIP P RIH from 370' to 463'. 18:45 19:30 0.75 463 463 PROD3 DRILL DHEQ P Shaiiow tested MWD and broke in Geopilot at 280 gpm 1,050 psi at 80 r m's. 19:30 22:30 3.00 463 8,270 PROD3 DRILL TRIP P RIH from 463' to 8,270', no problems going thru the window. (TOW at 8,239'-BOW at 8,252' . 22:30 22:45 0.25 8,270 8,281 PROD3 DRILL REAM P Washed down from 8,270' to btm at 8,281'. 22:45 00:00 1.25 8,281 8,352 PROD3 DRILL DDRL P Drilled 6 3/4" hole with Geopilot from 8,281' to 8,352' MD/3,601' TVD (71') ADT .4 hrs, 8.5 ppg MOBM MW, ECD 9.52 06/04/2007 00:00 08:15 8.25 8,352 8,766 PROD3 DRILL DDRL P Directionally drilled 6 3/4" hole in "D" sand lateral with Geopilot from 8,352' to 8,766' MD/ 3,639' ND ( 414') ADT 6.84 hrs. Lost highline power to rig and cam 08:15 08:45 0.50 8,766 8,766 PROD3 DRILL OTHR NP Lost highline to rig and camp, started rig engines. NOTE: rig and camp was back on hi hline at 10:10 hrs. 08:45 12:00 3.25 8,766 8,856 PROD3 DRILL DDRL P Cont. to directionally drill 6 3/4" hole from 8,766' to 8,856' MD/ 3,641' TVD, (90') ADT 2.68 hrs, 8.4 ppg MOBM, ave ECD 9.86 ppg. dri(fed thru 4 concretions for 35'. 12:00 00:00 12.00 8,856 10,070 PROD3 DRILL DDRL P Cont. to directionally drill 6 3/4" hole from 8,856' to 10,070' MD/ 3,671' ND, (1,214') ADT 7.88 hrs, 8.45 ppg MOBM, ave ECD 10.14 ppg. ave BGG 20 units max gas 92 units, drilled thru 8 concretions for 32'. No swee s. 06/05/2007 00:00 00:15 0.25 10,070 10,070 PROD3 DRILL SFTY P PJSM - Hazard Assessment & Reco nition on Drillin ahead. 00:15 12:00 11.75 10,070 10,538 PROD3 DRILL DDRL P Cont. to directionally drill 6 3/4" hole from 10,070' to 10,538' MD/ 3,678' ND (468') - ADT 8.53 hrs - 8.4 ppg MOBM - Ave ECD 9.98 ppg - Max gas 116 units - Drilled thru 6 concretions for 39'. No swee s. I Page 25 0€ 3A • ~ Tirrre L."a ~ - i~ te ~ _ . . Fra~ ~FQ ' ~~'~~, ~ur ~~ ~ ~S. De t~- E.'~ #ft Pi~~,se ~ '~. ~C~d~~ ~'~~ '~~ Su6cade` T ~C)~rt ~ 06/05/2007 12:00 18:30 6.50 10,538 11,469 PROD3 DRILL DDRL P Cont. to directionaliy drill 6 3/4" hole from 10,538' to 11,469' MD/ 3,695' ND (931') - ADT 4.29 hrs - Pump 35 BBLS Hi-Vis swee . 18:30 19:15 0.75 11,469 11,469 PROD3 DRILL CIRC P Cire sweep out of hole @ drilling rates of 305 GPM & 130 rpm - 25% increase in cuttin s. 19:15 00:00 4.75 11,469 11,937 PROD3 DRILL DDRL P Cont. to directionally drill 6 3/4" hole from 11,469' to 11,937' MD/ 3,703' ND (468') - ADT 6.74 hrs - 8.4+ ppg MOBM - Ave ECD 10.66 - Ave BGG 25 units - Max gas 131 units - Drilled thru 1 concretion for 6'. 06/06/2007 00:00 00:15 0.25 11,937 11,937 PROD3 DRILL SFTY P PJSM - Hazard Assessment & Reco nition on Drillin ahead. 00:15 12:00 11.75 11,937 12,537 PROD3 DRILL DDRL P Cont. to directionaity drili 6 3/4" hole from 11,937' to 12,537' MD/ 3,709' ND (600') - ADT 8.05 hrs - 8.4 ppg MOBM - Ave ECD 10.73 ppg - Max gas 140 units - Drilled thru 5 concretions for 29'. Pumped 35 BBL Hi-Vis Sweep @ 12,200' MD with 15% increase in returns. 12:00 00:00 12.00 12,537 13,150 PROD3 DRILL DDRL P Cont. to directionally drili 6 3/4" hole from 12,537' to 13,150' MD/ 3,706' ND (613') - ADT 8.61 hrs - 8.4 ppg MOBM - Ave ECD 11.29 - Ave BGG 25 units - Max gas 69 units - Drilled thru 6 concretions for 51'. 06/07/2007 00:00 00:15 0.25 13,150 13,212 PROD3 DRILL DDRL P Cont. to directionally drill 6 3/4" hole from 13,150' to 13, 212' M D- 3, 703' ND (62') - ADT 0.041 hrs - Dritied thru 1 concretion for 3': 00:15 00:30 0.25 13,212 12,685 PROD3 DRILL REAM T Discuss rock quality with geologist & engineer - Decision made to PUH & sidetrack. Backream from 13,212' to 12,685' MD. 00:30 01:30 1.00 12,685 12,695 PROD3 DRILL OTHR T Work string from 12,685' to 12,695' while MWD re-programs system in re aration for sidetracked welibore. 01:30 02:00 0.50 12,695 12,725 PROD3 DRILL DDRL T Begin troughing per DD from 12,695' to 12,725' MD. 02:00 04:00 2.00 12,725 12,737 PROD3 DRILL DDRL T Start Time Drilling per DD on open hole sidetrack from 12,725' to 12,737' MD. 04:00 12:00 8.00 12,737 12,826 PROD3 DRILL DDRL T Directionally drill new 6-3/4" hole w/Geopilot from 12,737' to 12,826' MD - 3723' ND (89') - ADT 7.59 hrs - Ave ECD 10.92' - Max gas 58 units - Drilled thru 2 concretions for 42'. 12:00 13:30 1.50 12,826 13,010 PROD3 DRILL DDRL T Continue to directionally drill 6-3l4" hole from 12,826' to 13,010' - ADT 1.26. 13:30 13:45 0.25 13,010 13,010 PROD3 DRILL REAM T Troubleshoot MWD due to erratic resistivity readings - Switch detection modes - POOH to 12,870' - RIH to BTM & t a ain. • ~ 'Tme Lq __ . Date :- ~r.orsr To ' L~ur ' S. ~e th E:' Qe tti Fhas~ .` ~ode` ' Subcocfe T' GU{~tl ' 06/07l2007 13:45 14:15 0.50 13,010 13,010 PROD3 DRILL OTHR T POOH fl13,010' to 12,870' MD - MWD appears to be working. RIH to 13,010' M D. 14:15 14:45 0.50 13,010 13,056 PROD3 DRILL DDRL T Continue drilling from 13,010' - 13,056' MD. ADT 0.28 hrs. 14:45 15:15 0.50 13,056 13,056 PROD3 DRILL OTHR T Continue to have tool problems - Trouble shoot MWD. 15:15 15:45 0.50 13,056 13,Q56 PROD3 DRILL OWFF T Survey off btm - Record SPR's. Monitor well - static. 15:45 16:15 0.50 13,056 12,620 PROD3 DRILL REAM T BROOH from 13,056' to 12,620' MD - 305 gpm @ 2750 psi, 85 spm, 120 rm 16:15 17:45 1.50 12,620 13,013 PROD3 DRILL OTHR T Troubie shoot MWD tools - Log 2 passes from 12,611' - 12,525' and 12,960' to 13,013' MD. 17:45 18:30 0.75 13,013 13,056 PROD3 DRILL TRIP T MWD appears to be working - Decision made per drlg engineer - RIH from 13,013' to 13,056' MD & continue drillin . 18:30 19:30 1.00 13,056 13,184 PROD3 DRILI DDRL T Continue to drill from 13,056' to 13,184' M D- 3727' TVD. ADT 0.59 hrs - Max Gas 58 units - Ave ECD 10.79. 19:30 19:45 0.25 13,184 13,184 PROD3 DRILL OWFF T Decision made to POOH due to MWD failure - unreliable resistivity readings. Monitor well - static. 19:45 20:00 0.25 13,184 12,905 PROD3 DRILL TRIP T Attempt to POOH on elevators from 13,184' to 12,905' MD - Well swabbing and not takin ro er fill. 20:00 00:00 4.00 12,905 9,419 PROD3 DRILL REAM T BROOH from 12,905' to 9,419' MD - 305 2750 si, 85 s m, 120 r m 06/08/2007 00:00 00:45 0.75 9,419 8,207 PROD3 DRILL REAM T Continue to back ream at 305 gpm, 2750 psi, and 120 rpm from 9,419' to 8,394' MD - POOH once stabilizers & bit across window from 8,394' to 8,207' MD. 00:45 01:00 0.25 8,207 8,207 PROD3 DRILL OTHR T Fiow check - Static - Pump Dry Job and Blow Dwn To drive. 01:00 03:00 2.00 8,207 369 PROD3 DRILL TRIP T POOH on elevators from 8207' to 369' M D. 03:00 03:15 0.25 369 88 PROD3 DRILL PULD T Set back 25 stds HWDP w/Jars and NonMa Flex DC's 03:15 04:15 1.00 88 88 PROD3 DRiLL OTHR T Check oil in GeoPilot - Plug into and download MWD 04:15 04:45 0.50 88 0 PROD3 DRILL PULD T LD Stab Float sub - TM - DGR, EWR, PWD - Break Bit 04:45 0530 0.75 0 88 PROD3 DRILL PULD T MU BHA# 13 - PU New Bit, DGR, EWR, TM - Same PWD 05:30 06:15 0.75 88 88 PROD3 DRILL OTHR T Plug in and UpLoad MWD 06:15 06:30 0.25 88 463 PROD3 DRILL TRIP T Trip in hole to 463' MD. 06:30 07:00 0.50 463 463 PROD3 DRILL DHEQ T Shailow Hole Test MWD @ 78 spm, 1051 si Page 27 af 3d . ~ i Time Go Date Frorn Tn Qur' S. C~e th E.' th Ptrase Code Subeade T-!CQM. ' 06/08/2007 07:00 12:00 5.00 463 11,846 PROD3 DRILL TRIP T Continue to TIH from 463' to 9326' MD - Ran out of SO Wt - Reamed from 9326' to 9512' MD @ 41 spm, 100 rpm, Trq 700Q, 1051 psi Continue to TIH from 9,512' to 11,098' MD - Reamed from 11,098' - 11,846' MD @ Same, Rot Wt = 75K. Filied pipe & tested MWD @ 2704', 5037', and 7368' MD. 12:00 13:00 1.00 11,846 12,951 PROD3 DRILL TRIP T PJSM - Continue RIH f/ 11,846' to 12,951' MD. 13:00 14:15 1.25 12,951 13,184 PROD3 DRILL SRVY T Madd Pass from 12,951' to 13,184' MD @ 100 rpm, Trq 8000, 81 spm @ 2850 psi (250-300 FPH}. Rot Wt = 81 K, SO = 0, PU = 145K si. 14:15 14:30 0.25 13,184 13,212 PROD3 DRILL DDRL. T Directionally Drill from 13,184' to 13,212' MD - 3,726' TVD - ADT 0.25 H rs. 1430 00:00 9.50 13,212 14,034 PROD3 DRILL DRLG P Continue Drilling from 13,212' MD to 14,034' MD - 3,714' TVD. ADT 4.67 hrs - 8.4+ ppg MOBM - Ave ECD 11.38 - Ave BGG 38 units - Max Gas 84 units - Drilled thru 2 concretions for 18'. Pumped Hi-Vis sweep @ 13,375' w/ 15°/o increase in cuttin s. 06/09/2007 00:00 00:15 0.25 14,034 14,034 PROD3 DRILL SFTY P PJSM - Hazard Assessment and Recognition on Driliing & Making connections. 00:15 12:00 11.75 14,034 15,088 PROD3 DRILL DDRL P Continue Drilling 6-3/4" hole with Geopilot from 14,034' MD to 15,088' MD - 3,733' ND. ADT 7.6 hrs - 8.4+ ppg MOBM - Ave ECD 10.26 - Max Gas 67 units - Drilled thru 6 concretions for 25'. 12:00 00:00 12.00 15,088 15,717 PROD3 DRILL DDRL P Continue Drilling 6-3/4" hole with Geopilot from 15,088' MD to 15,717' MD - 3,744' ND. ADT 6.62 hrs - 8.4 ppg MOBM - Ave ECD 11.49 - Max Gas 73 units - Drilled thru 9 concretions for 44'. 06/10/2007 00:00 02:00 2.00 15,717 16,033 PROD3 DRILL DDRL P Continue Driiling 6-3l4" hole with Geopilot from 15,717 MD to 16,033' MD 3750' TVD. ADT 1.3 hrs. 02:00 12:00 10.00 16,033 8,200 PROD3 DRILL REAM P BROOH from 16,033' MD to 8,200' MD @ 130 RPM - 89 spm - Initial pressure = 3800 psi. PU Wt 180K, SO Wt 0, Rot Wt 105, Trq 11,000. No problems encountered. 12:00 13:30 1.50 8,200 8,200 PROD3 DRILL CIRC P PJSM - Pump 30 BBL Hi-Vis sweep - Circulate & Recip from 8200' - 8100' MD @ 315 GPM, 2370 psi, 100 rpm - Sweep returned 15% excess - Continue circulatin 2 BU. 1330 13:45 0.25 8,200 8,200 PROD3 DRILL SFTY P PJSM - Cut and slip drilling line Hazard Reco nition Page 2$ c~f 34 • ~ Trne lo s Date Frarn Ta`: Qur S_ De th E: . th Fh~se , Code Subcade F; COM : 06/10/2007 13:45 14:45 1.00 8,200 8,200 PROD3 RIGMN SVRG P Cut & slip 74' Drlg line - I~spect & adjust brakes - Service Top Drive & Blocks - Monitor well. 14:45 16:15 1.50 8,200 11,380 PROD3 DRILL TRIP P Check coomie & RIH from 8200' to 11,380' MD (lost SO wt) Filled DP @ 11,002'. 16:15 21:00 4.75 11,380 16,033 PROD3 DRILL REAM P Wash and ream from 11,380' to 16,033' MD @ 3.5 bpm & 90 rpm. Pick u 2 sin les to reach TD. 21:00 00:00 3.00 16,033 16,033 PROD3 DRILL CIRC P Pump 30 bbl Hi-Vis sweep - Circ & Recip from 16,033' to 15,962' @ 300 gpm, 3900 psi, 130 rpm. Sweep returned 5% excess. Continue to circulate 2 BU's. 06/11/2007 00:00 00:15 0.25 16,033 16,033 PROD3 DRILL SFTY P PJSM on Displacement of SFOBM. Hazard assessment & designate spill cham for the 'ob. Q0:15 01:Q0 0.75 16,033 16,033 PROD3 DRILL CIRC P Continue circulating 8~ recip @ 300 GPM, 3900 psi, 130 rpm, Trq 10,000 ft-Ibs. 01:00 03:00 2.00 16,033 16,033 PROD3 DRILL CIRC P Displace to SFOBM @ 300 GPM, 3900 psi, 130 rpm. Obtain SPR's and flow check well - static. 03:00 10:15 7.25 16,033 370 PROD3 DRILL TRIP P LD 2 singles, Drop 1.88" OD Drift Rabbit on wire - POOH on elevators from 15,992' MD to 370' MD. Initial wts: PU 210K, SO 0, Rot 102K. 10:15 1030 025 370 370 PROD3 DRILL SFTY P Flow check static - PJSM Hazard Assessment & Recognition on LD B HA. 10:30 11:15 0.75 370 88 PROD3 DRILL PULD P LD 5 jts HWDP, Jars, 3jts NM Flex DC's, Stab & Float sub. 11:15 12:00 0.75 88 88 PROD3 DRILL OTHR P Plug in and download MWD. 12:00 13:00 1.00 88 0 PROD3 DRILL PULD P PJSM - LD MWD - GeoPilot & Bit - Clear Floor. 93:00 13:30 0.50 0 0 COMPZ CASINC RURD P RU equipment to run 4-1/2" slotted liner. 13:30 13:45 0.25 0 0 COMPZ CASINC SFTY P PJSM for liner run; Identify hazards and review rocedure and liner detail. 13:45 18:00 4.25 0 7,520 COMPZ CASINC RNCS P Run 4-1l2" BTC 11.6 ppf, L-80 Slotted Casing to 7,520' as follows: Shoe Joint - 80 jts csg - 75 jts csg w! Trq rings - XO - 22 jts Hydril 521 11.6 ppf L80 slotted csg - Hyd521 pup jt - XO. (177 jts total) Total of 75 Trq rings, 154 Hydroform centralizers w/no stop rings on jts #2 - 155. 18:Q0 19:00 1.QQ 7,520 7,582 COMPZ CASINC RNCS P PU Baker setting sleeve assembly - MU Baker Liner Receptacle Jt - Liner Pup Jt -"HR" Liner setting Sleeve. RD Casin E ui ment & Monitor well. ' Page 29 of 34 ~ ~ T~e Lo Qate Frarxe Tc~ ' ~ur S. L3e th E. th Fhase Cod~ '' SuEieode T CC7M " 06/11/2007 19:00 00:00 5.00 7,582 14,172 COMPZ CASIN( RUNL P RIH with 4-1/2" liner on 4" DP from 7582' to 14,172'. Fill pipe every 15 stds. Lost SO wt @ 11,285' - Rotate liner to 14,172' MD @ 25 rpm. Rot wt 55K, Pu wt 150K, Tr 7000 ft-Ibs. 06/12/2007 00:00 02:15 2.25 14,172 16,033 COMPZ CASIN( RNCS P Continue FtIH w/4-1/2" liner on 4" DP - Rotating from 14,172' MD to 16,033' @ 25 rpm - Trq Limit set @ 8K. Recording Trq & Drag every 5 stands. PU Wt 185k, SO Wt 0, Rot 35k. Tight hole, worked pipe from 15,808' MD to Btm - Increased Trq limit to 14K ft-Ibs. Ta ed btm 16,042' MD. 02:15 03:00 0.75 16,033 8,469 COMPZ CASINC CIRC P Drop 29/32" bail & circulated 850 sks down to ball seat - Pressured up to 4400 psi to release from running tool. PU Wt 155k, SO Wt 55k. Tagged top of liner @ 8469' MD. (9' below tally de th 03:00 06:15 3.25 8,469 0 COMPZ CASINC RUNL P Flow check static - Blow Dwn TD - POOH from 8,469' MD to Baker settin tool - LD Liner Settin Tool. 06:15 06:30 0.25 0 0 COMPZ CASIN( OTHR P Cleared Rig Floor. 06:30 07:00 0.50 0 344 COMPZ FISH PULD P PU & MU Baker Whipstock retrieving hook assembly with 1 Jt 3.5" HWDP, Flt Sub, Bumper sub, Oil Jars, XO, 3 Stds ush i e. 07:00 09:45 2.75 344 8,251 COMPZ FISH TRIP P TIH from 344' to 8,251' MD fiiling pipe 2,761' - 5,187' - 7,284' MD. 09:45 10:00 0.25 8,251 8,251 COMPZ FISH CIRC P Wash whipstock siot @ 8,244' MD @ 7 bpm, 1700 psi. PU Wt 130, SO 0 si. 10:00 10:15 0.25 8,251 8,244 COMPZ FISH FISH P Engage hook @ 8244' MD - Jar Free with 70K over. PU Wt 150K 10:15 12:00 1.75 8,244 7,192 COMPZ FISH TRIP P Monitor well on TT- Static. POOH from 8,244' to 7,192' MD. Dis lacement 1 bbl lon . 12:00 14:00 2.00 7,192 334 COMPZ FISH SFTY P PJSM - Hazard Recognition - CONT POOH to BHA 14:00 14:30 0.50 334 334 COMPZ FISH PULD P Stand back DC's, LD Oil Jars & Bum er sub. 14:30 16:00 1.50 334 0 COMPZ FISH PULD P LD Whipstock Assembly - Clean & Clear ri floor of tools. 16:00 16:30 0.50 0 0 COMPZ CASIN( RURD P PU & RU Tools for Hook Hanger Assembl 16:30 16:45 0.25 0 0 COMPZ CASIN( SFTY P PJSM - Review procedures & Hazards associated with hook hanger and PU slim hole MWD tools. 16:45 19:00 2.25 0 380 COMPZ CASINC PUTB P PU'D' Laterai Hook HangerAssembly with ECP Packer, Inner String, slim hole MWD - RIH and shallow tested tools 380' MD. Page 30 of 34 ~ ~ ' Trme Lo s 'Qafe From ; To Qtir' S. De t[~r E. De tE~ E'hase ~ode ': Subeode T; CQM" ' 06/12/2007 19:00 21:30 2.50 380 8,407 COMPZ CASIN( RUNL P RIH with Hook Hanger Assembiy and running tool on 4" DP as follows: 4.5" STL BENT jt Blank casing w/ full mule shoe - 4.5" XO Jt - 4.5" Pup jt - PayZone E~ernal Casing Packer - 4.5" Pup Jt - Space out pup jt - 2 Marker Pup Jts - 3 jts 4.5" 11.6 ppf L-80 BTC Blank Csg - BTC Hanger pup jt - Baker Model B-1 Hook Hanger. *`Went into welibore and tagged XO Bushing in B Lateral Liner @ 8407' M D*` 21:30 23:00 1.50 8,515 8,515 COMPZ CASINC RUNL P POOH to above D Lat Liner @ 8222' and rotate 3x. On the 2nd attempt entered D-Lateral. PUH and oriented to High side. PU Wt 150K - SO Wt 60K. Hooked window @ 8252' MD with tool face 3 deg Right. Unhook and PU to 8222' and orient tool face 180 deg - SO to 8264' witnout tag. (6' below calculated tag). PU to 8222' and orient High Side & ReHook window @ 8252' with tool face @ 3 deg right. Slack 25K Dwn Wt - Confirmed hook was ositioned ro erl . 23:00 00:00 1.00 8,515 8,515 COMPZ CASINC OTHR P Dropped ball & pumped down to seat @ 2.8 bpm, 900 psi. Ball on seat at 2000 psi - Quickly pressured up to 2700 psi to open valve - Re-Zero stroke counter & inflate ECP with a totai of 0.25 bbls at 2800 psi - Increased PP to 4000 psi to release running tool - PUH to confirm. Set top of HH at 8,252' MD with Mule Shoe @ 8515.74'. 06/13/2007 00:00 02:30 2.50 8,515 100 COMPZ CASIN( RUNL P Compieted pumping to inflate packer, blow ball seat & release from Hook Hgr setting tool. Blow Down - Flow check static - POOH to HH setting tool. 02:30 03:30 1.00 100 0 COMPZ CASINC RURD P Break Hook Hgr setting tool and lay down - Change elevator and lay down slim hole MWD and innerstrin . 03:30 03:45 0.25 COMPZ CASINC OTHR P Clear and Clean Rig Floor 03:45 04:00 0.25 COMPZ DRILL SFTY P PJSM - Discussed hazards with LD 4" DP via mouse hole to i e shed. 04:00 12:00 8.00 COMPZ DRILL PULD P Lay Down 396 jts of 4" DP to pipe shed. 12:00 12:15 0.25 COMPZ DRILL SFTY P PJSM - Discuss hazards and rocedures with LD 4" DP 12:15 1430 2.25 COMPZ DRILL PULD P Continue LD 4" DP, HWDP, and H brid DC's. 14:30 14:45 0.25 COMPZ RIGMN SFTY P PJSM - Hazard recognition for Cut & sli DL. Page 31 af 3A. i • Time Lo Date ~r~rn Tci. ~ur S. De th E. De th Fhase : Coc~~ ; SuFac~de 'T 'COM : 06/13/2007 14:45 15:45 1.00 COMPZ RIGMN SVRG P Cut & siip 81' of driiling line - Inspect Brakes - Check Crown-o-matic - Lube blocks, TD, & Crown 15:45 16:15 0.50 COMPZ RPCOh RURD P RU equipment to PU 4-1/2" Tbg 16:15 16:30 0.25 COMPZ RPCOb SFTY P PJSM - Review Hazards with PU Tbg 16:30 00:00 7.50 COMPZ RPCOh PULD P RIH picking up 4-1/2" completion tbg 258 ts total) 06l14/2007 00:00 00:15 0.25 COMPZ RPCOh SFTY P PJSM - Hazard recognition & awareness for POOH w/ tb . 00:15 02:45 2.50 COMPZ RPCOh PULD P Continue to POOH with 4-1/2" Tbg and racking back in the derrick. Total of 86 stands 258 'ts . 02:45 03:15 0.50 COMPZ RPCOh OTHR P Pull wear ring. 03:15 04:45 1.50 COMPZ RPCOh RURD P PU clamps and protectorizers, ESP sheeve, and toofs from beaverslide. Pre-Job count = 255 Ciamps & 13 SS Bands. 04:45 05:00 0.25 COMPZ RPCOh SFTY P PJSM with Halliburton Wireline, Centralift, and crews to review job procedures and discuss hazards with runnin ESP com letion. 05:00 05:30 0.50 COMPZ RPCOh RURD P PU Centraiift Perforated Crossover w/Screen intake, pup jt, and 2 jts 4-1/2" 12.6# L-80 IBTM tbg. PU Internal um assembl . 05:30 07:00 1.50 COMPZ RPCOh SLKL P Wireline RIH to seat pump assembly - Install D&D Pack Off with slip stop - Test on chart to 1000 psi (Good test). RD Slickline. PU Pup jt, Unique dischar e sub, u 't. 07:00 0730 0.50 COMPZ RPCOti PULD P Rack back pump housing, 2 jts tbg, and dischar e sub. 07:30 10:00 2.50 COMPZ RPCOh PULD P PU & MU Weatherford Pump Gauge, Motor, Lower and Upper Tandem seal assembl . 10:00 11:00 1.00 COMPZ RPCOh PULD P PU control wire from spool house 8~ RU sheeve on rig floor. Piug in & test connections, service motor. 11:00 12:00 1.00 COMPZ RPCOh PULD P Clamp gauge control line and cabie to motor & tandem seal assembl . 12:00 12:15 025 COMPZ RPCOh SFTY P PJSM to review RIH with ESP com letion. 12:15 13:15 1.00 0 135 COMPZ RPCOti PULD P PU Assemb(y from Btm of motor/centralizer to zpup jt above discharge sub (135') Connect cap tube to ressure dischar e sub. 13:15 16:00 2.75 135 2,270 COMPZ RPCO RCST P RIH with ESP 4-1/2" 12.6# L-80 IBTM SCC Tb . 16:00 20:00 4.00 2,270 2,270 COMPZ RPCOh OTHR T ESP cable kinked - Cable wedged between rollers in the spooling unit. Resulted in - 70' of damaged line. Centralift spliced cabie & checked continuit . Page, 32 csf 3A ~ • Ti~ne Lo s ;t~~t~ Frc~in To : ~ur . S.. De th E• De th Phase Cade Subcod~ T: GOM ' 06/14/2007 20:00 00:00 4.00 2,270 4,700 COMPZ RPCOti RCST P Continue RIH with 4-1/2" 12.6# L-80 Tbg to 4700' MD as follows: 136 jts of 4-1/2" 12.6# L-80 Tbg, Camco GLM w/ DV, 17 jts tbg "" S lice located 10' below ~t# 77 "' 06/15/2007 00:00 05:00 5.00 4,700 8,170 COMPZ RPCOh RCST P Continue R!H with 12.6# L-80 4-1/2" tbg: 50 jts of 12.6# L-80 4-1l2" tbg - GLM #1 with Shear Vlv - 67 jts of tbg. Ran a total of 262 jts of tbg - 151 Cannon Clamps - 15 SS Bands - 2 Flat Guard Clamps - 1 Motor Protector - 2 Pump protectors. Tested cable eve 1000 feet while RIH. 05:00 05:30 0.50 8,170 8,202 COMPZ RPCOti RCST P PU and MU Landing jt and Hanger - PU Wt 115k, SO Wt 52k. Landed with Btm of Centralizer @ 8201.76, XO screen intake @ 8139' GLM #1 @ 2112 and GLM #2 3883' MD. 05:30 09:00 3.50 8,202 8,202 COMPZ RPCOh OTHR P Spiice cabie and connect penetrator with 3 SS Bands - Check continui . 09:00 10:00 1.00 8,202 8,202 COMPZ RPCOh DHEQ P Land Tbg with 17k on hanger - Run in LDS - Test Upper & Lower seals to 5000 psi for 10 minutes, Good Test - LD Landin 't - Clear Floor. 10:00 10:15 0.25 COMPZ RPCO SFTY P PJSM - Recognize hazards and procedures with ND BOP - Heavy loads and inch oints. 10:15 11:15 1.00 COMPZ RPCO NUND P ND BOPE - Set back & Secure. 11:15 14:15 3.00 COMPZ RPCOti NUND P NU Tree - Test void with 5000 psi for 10 min - Continuit test failed - W O O 14:15 15:30 1.25 COMPZ RPCOh NUND T ND Tree and NU BOP to troubleshoot electrical failure. 15:30 16:30 1.00 COMPZ RPCOh PULD T RU Lubricator - Pull BPV - Set 2 way check - RD Lubricator. 16:30 17:15 0.75 COMPZ WELCT BOPE T Fill stack with water - Test BOP Flange, Blinds, and choke line to 250 and 2500 si. 17:15 18:00 0.75 COMPZ RPCOh PULD T RU Lubricator - puil 2 way check - Set BPV - RD Lubricator. 18:00 19:00 1.00 COMPZ RPC06 PULD T MU Landing jt - Back out LDS - Pull Tb Han er to floor. 19:00 21:30 2.50 COMPZ RPCOti OTHR T Centralift tested pigtale cable below hgr - Good test. Tested Penetrator - Test failed. Hanger scratched while PUH - Vetco Gray Rep dressing the scratches on the hrg and replacing seal rings. Centralift changed out penetrator with new. Continuity test passed. RIH with hanger and land with 17k. 21:30 22:15 0.75 COMPZ RPCO DHEQ T Run in LDS - Test Upper and Lower seals to 5000 psi for 10 minutes - Good Test. 22:15 23:00 0.75 COMPZ RPCOh NUND T Pull landing jt - ND BOPE. Page 33 of 34 ~ • :TiriYe Lo [7ate Frarn Ts~, ' Qur S. De th E. De th Fhase : Ccsde : Subcode T'' COM : 06/15/2007 23:00 23:30 0.50 COMPZ RPCOh DHEQ T Check and record electrical integrity and conductivit - Good Test. 23:30 00:00 0.50 COMPZ RPCOh NUND T NU Tree 06/16l2007 00:00 00:30 0.50 COMPZ RPCOh NUND T Continue to NU Tree 00:30 01:00 0.50 COMPZ RPCOh DHEQ P Test tree flange to 5000 psi for 10 min - Test electrical and conductivity on ESP penetrator - Good tests. Instail accuator valve on annulus. 01:00 02:15 1.25 COMPZ RPC04 RURD P RU Scaffolding & PU Lubricator - Pull BPV and set 2-wa check. 02:15 02:30 0.25 COMPZ RPCOh DHEQ P Test Tree to 5000 psi for 10 min test - Good. 02:30 03:00 0.50 COMPZ RPCOh RURD P RU Lubricator - Pull 2 Way check. 03:00 03:45 0.75 COMPZ RPCOh OTHR P Continue to clean pits - wipe down tree. 03:45 04:15 0.50 COMPZ RPCOh RURD P PJSM - RU Little Red - Test lines to 2500 si. 04:15 10:45 6.50 COMPZ RPCOh CIRC P Disptace well with 362 bbls of diesel @ 1 bpm - Final Circulation pressure 200 si. 10:45 12:00 1.25 COMPZ RPCOti OTHR P RU Lubricator - Set BPV - Clean pit #5 and rockwasher - Install blank flanges on tree - Final SICP 250 psi, SITP 100 psi. Suck out cellar - Rig released @ 1200 hrs. Pa~e 34 of 34 ' i • 1J-120'A' Sand Liner Detail wen: 1J-120 "+~-~'' 41/2" Slotted and Blank Liner ~ate: 5/17/2007 ConQCOPhiliips Aiaska, inc. DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 1 LENGTH TOPS 8758.26 8758.26 8758.26 - - " 8758.26 4" DP to Surface =_> 8758.26 XO 4.5" XT39 x 3-1/2" IF 2.00 8758.26 Baker Liner setting tool with pup jt 11.46 8760.26 5.5"x 7.63" Baker "HRD" ZXP Liner Top Pkr 19.02 8771.72 "RS" Packoff Seal Ni le, 6.07" OD / 4.87" ID 2.85 8790.74 5.5" X 7.63" "Flex-Lock" Liner H r, 6.59" OD/ 4.85" ID 9.84 8793.59 190-47 Seal Bore Ext, 6.29" OD / 4.75" ID 19.64 8803.43 XO Sub 5.5"H d 563 X 4.5"H d 521 5.99"OD X 3.94" I 1.40 8823.07 4-1/2" H dril 521 11.6 f, L-80 " Blanks - 21 Jts 859.38 8824.47 XO Sub 4.5"H d 521 X 4.5", BTC 5.99"OD X 3.94" ID 1.66 9683.85 Jts 116 to 128 13 Jts 4-1/2" BTC w/TQ Rin s 11.6 f, L-80 * Blanks 554.54 9685.51 Jts 70 to 115 46 Jts 4-1/2" BTC w/TQ Rin s 11.6 f, L-80 Slotted Casin 1965.18 10240.05 Jts 63 to 69 7 Jts 4-1/2" BTC 11.6 f, L-80 Casin * Blanks 300.63 12205.23 ~ts as to s2 15 Jts 4-1/2" BTC 11.6 f, L-80 Slotted Casin 638.71 12505.86 Jts 41 to 47 7 Jts 4-1/2" BTC 11.6 f, L-80 Casin * Blanks 300.74 13144.57 ~ts 2a to ao 17 Jts 4-1/2" BTC 11.6 f, L-80 Slotted Casin 733.52 13445.31 ~ts 2o to 23 4 Jts 4-1/2" BTC 11.6 f, L-80 Casin * Blanks 170.79 14178.83 ~ts 2 to ~s 18 Jts 4-1/2" BTC 11.6 f, L-80 Slotted Casin 763.85 14349.62 Swell Packer #2 19.50 15113.47 ~ts ~ to ~ 1 Jts 4-1/2" BTC 11.6 f, L-80 Casin * Blanks 41.79 15132.97 Swell Packer #1 19.57 15174.76 41/2" Pu Jt, 12.6 f, L-80 w/ oran e eeled bottom 5.67 15194.33 Bottom OF SHOE __> 15200.00 TD 6-3/4" hole @ 15,822' MD / 3952' TVD 7-5/8" Shoe 9,945' MD ND 3871' Run 1 s iro lider er "t. Put sto rin in middle of 't with the centrailizer floatin on the bttm half of 'oint. on 'oints #2 thru Jts #116 Run tor ue rin s in the TOP 2500' of the BTC-M liner. Jts # 70 thru Jt# 128 Ran total o f 32 'ts BTC Blank= 1368.5', 96 'ts BTC Slots= 4101.26' & 21 'ts H d 521 Blank= 859 .38'. Slots are 0.125" wide x 2.5" lon x 32 sfo/ft. w/ 32 2.5" lon x.125" 4 U Wt 215k Circumferential ad'acent rows,3" Centers sta ered 18de . 3' non-slotted ends. Rot Wt 105k Ran 7 Constrictor ackers 10215', 12230', 12495', 13160', 13440', 14,195' Block Wt 34k and 14,335'. Ran shoe 'oint slick. Tor ued BTC liner w/o tor ue rin s to 3000 ft-Ibs, w/ tor ue rin s to 5800 ft-Ibs, H d521 to 4700 ft-Ibs ~Used Run-N-Seal thread compound on all connections. All drifted w/ 3.875" rabbit. Supervisors: G.R. Whitlock / N. Woods / S. Shultz ~ ~ 13-Ju1-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-120 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 28.00' MD Window / Kickoff Survey 0.00' MD (if applicable) Projected Survey: 15,822.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 D Date ~ ~6~ Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) a,~~- ~~cS ~ 1 J-120 Top Job Doyan 141 OS-04-2007 PTD 207-045 . ~ ~c ~~~ ~~ ~ ~ j' ~ ~. ~ Tom 1 J-120 failed to get cement to surface. Daryl G~adden told me that they didn't loose circulation but it did slow down. Original cement job was pumped as follows; 50 BBL's CW100 wash 49 BBL's Spacer (with red die) 529 BBL's 10.7# Lead Cement 81 BBL's 12# Tail Cement One inch tubing was run in as far as possible and it's ended as follows; 165' Below RKB 137' Below Wellhead 57' Below Conductor The rig circulated 50 BBL's of water to clean up hole. Red die was at or near surface. Schlumberger followed water with 10.7# cement and it took 46 BBL's to get cement to the pits. Got a weight of 10.7# and a sample at SOBBL's of cement pumped. Pumped a total of 59 BBL's of cement on top job. Bob Noble ~ ~ Maunder, Thomas E (DOA) fram: Thamas E Maunder[tom_maunder~admin.state.ak.us] Sent: Friday, May 04, 2007 4:27 PM To: Hartwig, Dennis D Cc: Thomas, Randy L; Doyon 141 Company Man Subject: Re: 1J-120 Surface Cemenf Job Dennis, This acknowledges our conversation. Unfortunate with the decreasing returns. Based on what was seen at the shaker, the cement shouldn't be far ciown. Keep us informed of the progress. I did speak with the Inspector at the rig. Tom Maunder, PE AOGCC 529-1645 ----- Original Message ----- From: "Hartwig, Dennis D" <Dennis.D.Hartwig@conocophillips.com> Date: Friday, May 4, 2007 1:51 pm Subject: 1J-120 Surface Cement Job To: Thomas Maunder <tom maunder@admin.state.ak.us> Cc: "Thomas, Randy L" <Randy.L.Thomas@conocophillips.com>, Doyon 141 Company Man <n1334 @conocophillips.com> > Tom, > > Per our recent phone conversation, the surface cement job on the > 1J-120 did not qo as planned. Details are listed below; > > o No apparent issues running the 10 ~" casing to TD of 13 '~" Hole > at approximately 4,107'MD ~ casing ran to bottom well. > > o Saw the CW1Q0 spacer (50bbls) come across shakers > > o Did not see the 50 bbls of Mudpush (with red dye) following CW100 > > o At 2000 strokes into displacement started to lose returns (Plug > bumped @ 3657stks) > > o When plug bumped the flow @ surface had decreased from 3~ bbls > to approx ~ bbl. > > Per our conversation we estimate the top of cement tp be close to > surface and are currently preparing for a top job. > > If you have any concerns or require more detail please feel free to > contact me. > > Regards...Dennis > > Dennis Hartwig > Drilling Engineer > ConocoPhillips Alaska, Inc. > > Office : 907-265-6862 > Cell : 907-980-1433 > Fax : 907-265-1535 > > 1 ~ Randy Thomas Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 ~ Re: Kuparuk River Field, West Sak Oil Pool, 1J-120 ConocoPhillips Alaska, Inc. Permit No: 207-045 Surface Location: 1875' FSL, 2357' FEL, SEC. 35, T11N, R10E, UM Bottomhole Location: 359' FSL, 1992' FEL, SEC. 24, T11N, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (~~59-3607 (pager). DATED this~ day of April, 2007 C cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Cono~o h i I I i s p Alaska Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone(907)265-6830 Email: Randy.L.Thomas@conocophillips.com March 29, 2007 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 ~ ~~cE~vEQ MAR 3 0 2007 Alask~ ~~t ~ ~a~ ~~~~. ~,~mission ~nchara~e Re: Applications for Permit to Drill, West Sak Producer, 1)-120, 1J-120 Ll, 1J-120 L2 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore producer well, a trilateral horizontal well in the West Sak "A2", "B" and °D" sands. The main bore of the well will be designated 1J- 120, and the lateral bores of the well will be designated 1J-120L1 and 1J-120L2. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for each of these well bores. The expected spud date of iJ-120 is April 27, 2007. If you have any questions or require any further information, please contact Dennis Hartwig at 265-6862. Sincerely, m. ~~ .,. , ....._. , ..... ~:,.~.~~. ~.,1 ~ ~..~,~..__~--. ~ _...,.~ Randy Thomas Greater Kuparuk Area Drilling Team Leader ~ STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ~~~~rv~D ~r~, ~~.a~ 3 a ~007 ~€sska Oi~ 6~ Gas Cons. Commission ~~~~~ 1a. Type of Work: Drill Q Re-drill ^ Re-entry ^ 1b. Current Well Class: Exploratory Development Oil ~. Stratigraphic Test ^ Service ^ Development Gas ~ Multiple Zone^ Single Zone ~ 1c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillipsAlaska, Inc. 5. Bond: ~ Bfanket Single Well Bond No. 59-52-180 • 11. Well Name and Number: 1J-120 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 16320' • ND: 3947' ' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1875' FSL, 2357' FEL, Sec. 35, T11 N, R10E, UM ' 7. Property Designation: ADL 25661~25650 ~ West Sak Oil Pool • Top of Productive Horizon: 587' FNL, 1874' FEL, Sec. 36, T11N, R10E, UM 8. Land Use Permit: ALK 471, 468 13. Approximate Spud Date: 4/27l2007 Total Depth: 359' FSL, 1992' FEL, Sec. 24, T11 N, R10E, UM ~ 9. Acres in Property: 2560 14. Distance to Nearest Property: < 1 mile . 4b. Location of Well (State Base Plane Coordinates): SurFace: x- 558854 - 5945688 ~ Zone- 4 y' 10. KB Elevation ~~9 '~jfs~ y~2 ~~ (Height above GL): 2$' RKB feet 15. Distance to Nearest Well within Pool: 1D-141L1 , 326~ ~ 16. Deviated wells: Kickoff depth: 300 - ft. Maximum Hole Angle: 94° deg 17. Maximum Anticipated Pressures in psig (see 2o AAC 25.035) Downhole: 1855 psig ~ Surface: 1421 psig ' 18. Casing Program if ti S Setting Depth Quantity of Cement Size peC iCa ons Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling length MD ND MD ND (including stage data) 42" 20"x34" 94# K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticCrete 13.5" - 10.75" 45.5# L-80 BTC 4100' 28' 28' 4100' • 2472' 630 sx AS Lite, 180 sx DeepCRETE 9.875" - 7.625" 29.7# L-80 BTCM 10092' 28' 28' 10092' . 3970' - 520 sx DeepCrete 6.75" • 4.5" 11.6# L-80 BTC 7379' 8941' 3737' 16320' . 3947' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (k): Junk (measured) Casing Length Size Cement Volume MD TVD Cond uctor/Structu ral Surface Intermediate Production Liner Perforation Depth MD {ft): Perforation Depth ND (ft): 20. Attachments: Filing Fee a BOP Sketch ~ Drilling Program Q Time v. Depth Plot ~ Shallow Hazard Analysis ~ Property Plat ~ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. ContaCt Dennis HBrtwig @ 265-6862 Printed Namg,,, ' Randy Thomas ritie Drilling Team Leader ~~.. Signature l~~,.~, ~L, ~"`~~,~~r~ Phone ~ZE~ ~,~~' 7 c~ Date '~~Z-~C ,t7 ~ nAll D k Commission Use Only Permit to Drill Number: ~~~' ~~~ API Number: 50-Q~- Z~3SZ"'~ Permit Approval Date: •~, 0~ See cover letter forotherrequirements Conditi0ns of app~oval : If box is checked, well may not be used to explore for, test, or produce coalbed me ane, gas hydrates, or gas contained in shales: Samples req'd: Yes ^ No ~ Mud log req'd: Yes ^ No [/~ Other: '~~~ ~,n,y ` 3Q7,~S~,_ H2S measures: Yes No D ectional svy req'd: Yes [ No ^ ~" /~ APPROVED BY THE COMM~SSION DATE: ~~~ ``~ , COMMISSIONER . Form 10-401 Revised 12/2005 ,' ~ y~ q~ Submit in Du licate ».w' a d fi'~ t~~~ a l~.,. ~~~~ ~~ '~/~,2 ~D'I ~ A~ation for Permit to Drill, Well 1 J-120 Revision No.O Saved: 28-Mar-07 Permit It - West Sak Well #1J-120 Producer ~~~ r.~ ~t Application for Permit to Drill Document r~~ C~ ~ ~~ w~ii vpru~ Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (fl ....................................................................................................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ....................................................................................................... 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Drilling Hazards Information ...................................................................................3 Requirements of 20 AAC 25. 005 (c) (4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 4 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 4 6. Casing and Cementing Program ............................................................................ 4 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Drilling Fluid Program ............................................................................................. 4 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 4 Surface Hole Mud Program (extended bentonite) .................................................................................. 5 Intermediate Hole Mud Program (LSND or MI VersaPro Mineral Oil Base) .......................................... 5 Lateral Mud Program (MI VersaPro Mineral Oil 8ase) ........................................................................... 5 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10. Seismic Analysis ..................................................................................................... 6 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 6 11.Seabed Condition Analysis ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(19) ................................................................................................ 6 1J-120 PERM/T IT Page 1 of 8 Printed: 28-Mar-07 ~~~~~~~~~~ • A~ation for Permit to Drill, Well 1 J-120 Revision No.O Saved: 28-Mar-07 12. Evidence of Bonding ............................................................................................... 6 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6 13. Proposed Drilling Program ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 8 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 8 15. Attachments ............................................................................................................. 8 Attachment 1 Directional Plan ................................................................................................................ 8 Attachment 2 Drilling Hazards Summary ............................................................................................... 8 Attachment 3 Cement Loads and CemCADE Summary ....................................................................... 8 Attachment 4 Well Schematic ............................................................................................................... 8 Attachment 5 1/4 Mile Radius Effect for Injector ... ...................................................................8 1. Well Name Requirements of 20 AAC 25.005 (fl Each well must be identifred by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identiFed by a unique name and API number by adding a su~x to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1J-120. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) 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: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (8) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 1,875' FSL, 2,357' FEL, Section 35, T11N, R10E ASP Zone 4 NAD 27 Coordinates RKB Elevation 109.0' AMSL Northings: 5,945,688 Eastings: 558,854 Pad Elevation 81.0' AMSL Location at Top of Productive Interval 587' FNL, 1,874' FEL, Section 36, T11N, R10E West Sak "A2" Sand ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 10 092 Northings: 5,948,552 Eastings: 564,591 Total Vertical De th RKB: 3,910 Total Vertical De th, SS: 3,801 Location at Total De th 359' FSL, 1 992' FEL, Section 24, T11N, R10E ASP Zone 4 NAD 27 Coordinates M2dSUl'2d DE th, RKB: 16 320 ' Northings: 5,954,777 Eastings: 564,418 Total Vertical De th, RKB: 3,947 Total Vertical De th SS: 3 838 1J-120 PERMIT 1T Page 2 of 8 Printed: 28-Mar-07 .~--. ~~~~~~~~+~~~ ~ and (D) other information required by 20 AAC 25.050(b); A~ation for Permit to Drill, Well 1J-120 Revision No.O Saved: 28-Mar-07 Requirements of 20 AAC 25.050(b) If a well rs to be intentionally deviated, Yhe application for a Permit to Drill (Form 10-401) must (I) indude a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the eactent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the 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 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: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC Z5.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1)-120. For all operations the stack will be equipped with 3-1/2" to 6" variable bore rams in the uppermost ram cavity, blind rams in the middle cavity, and 7-5/8" rams in the lowermost cavity. See attached diagram entitled ~~Doyon 141 West Sak 2004 3ksi BOP Configuration" for clarification. Upon initial nipple up, and at intervals of no more than 14 days thereafter, a test plug will be set below the lowermost rams, the annular preventer will be tested to 1,500 psi and the blind rams and upper rams will be tested to 3,000 psi. (This test will test the shell and end connections of the lowermost ram). The lowermost rams will be closed and tested to 3,000 psi on a 7-5/8" OD. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identifred in the application: (4) information on drilling hazards, induding (A) the maximum downhole pressure tf~at may be encountered, crite~ia used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 1J area vary from 0.44 to 0.47 psi/ft, or 8.5 to 9.0 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom hole pressure data from Nearby West Sak wells The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak A2 sand formation is 1,421 psi, calculated thusly: MPSP =(3,947 ft TVD)(0.47 - 0.11 psi/ft) = 1,421 psi < (e) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: 1J-120 Drilling Hazards Summary. 1J-120 PERMIT /T Page 3 of 8 Printed: 28-Mar-07 ~ ~ g ~ ~ ~ ae ;v,M1.q ~ ~ {'~ ~ ~ ,,.,,, ~ A ~ ~ation for Permit to Drill, Well 1J-120 Revision No.O Saved: 28-Mar-07 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on Fle with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests; as required under 20 AAC 25.030(~; 1]-120 will be completed with 7-5/8" intermediate casing landed at the top of the West Sak A2 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 ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to 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: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summary Hole Top Btm Csg/Tbg Size Weigh Length MDlND MD/TVD OD in in t Ib/ft Grade Connection ft ft ft) Cement Pro ram 20 x 34 42 94 K55 Welded 80 28 / 28 80 / 80 Cemented to surface with 260 cf ArcticCRETE BTC Cemented to Surf'ace with 10-3/4 13-1/2 45.5 L-80 special 4,100 28 / 28 4,100 /2,472 630 sx ASLite Lead, drift 180 sx DeepCRETE Tail Cement Top planned @ 7-5/8 9-7/8 29.7 L-80 BTCM 10 092 28 / 28 10,092 / 3,910 s,379' MD / 2,989' ~rv~. , Cemented w/ 520 s3c Dee CRETE 4-1/2 6-3/4" A Sand 11.6 L-80 BTC 7,379 8.941 / 16,320 / 3,947 Slotted- no cement slotted --ateral (11-1z0) 3,737 4-1/2 6-3/4" B Sand 11.6 L-80 BTC 7 216 8,841 / 16,057 / 3,803 slotted- no cement slotted ~ateral (1.7-120 ~1) 3,720 4-1/2 6-3/4" ~ Sand 11.6 L-80 BTC 7,709 8,341 / 16,050 / 3,737 Slotted- no cement slotted ~ateral (i1-120 ~z) 3,626 4 1/2 NA 12.6 L-80 IBTM 8,232' 28 /28 8,232 / 3,600 Productian Tubing tubin # 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) 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: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(l~)(2); A 21-1/4", 2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of 1)-120. Please see diagrams of the Doyon 141 diverter system on file with the Commission. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) 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: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: 1J-120 PERMIT IT Page 4 of 8 Printed: 28-Mar-07 g,~ ~~~~ ~ ~ a ,~ ~ a `~ t ~ ~ . ~ ~.`°~ ~.,~. ~ SurFace Hole Mud Program (extended bentonite) ~ation for Permit to Drill, Well 1 J-120 Revision No.O Saved: 28-Mar-07 S ud to Base of Permafrost Base of Permafrost to 10-3/4" Casin Point Initial Value Final Va/ue Initia/ Value Final Value Density (ppg) 8.9 9.2 9.5 9.6 Funne~ viscosity 150 250 200 300 seconds Yie/d Point 50 70 30 50 cP) Plastic Viscostiy 20 45 15 20 Ib/100 s pH 8.5 9.0 8.5 9.0 API Filtrate NC 8A 5 0 7 0 (cc / 30 min)) . . *9.6 ppg if hydrates are encountered ' Intermediate Hole Mud Program (LSND) 10-3/4" Csg Shoe to 7-5/8" Csg Point Value Density (ppg) 8.8 - 8.9 Funnel Viscosity 45-60 (seconds) Plastic Viscostiy 12 - 18 (Ib/100 sf) Yield Point 26 - 35 (cP) API Filtrate 4- 6 cc / 30 min) Chlorides (mg/I) <500 pH 9.0 - 9.5 MBT <20.0 Intermediate Hole Mud Program (if MI Versa Pro Mineral Oil Base is used in Intermediate) 10-3/4" Csg Shoe to 7-5/S" Csg Point Value Density (ppg) 8.8 - 8.9 Plastic Viscostiy (Ib/100 sf) 19 - 20 Yield Point (cP) 18 Oil / Water 80 / 20 Electrical Stability >600 Lateral Mud Program (MI VersaPro Mineral Oil " Base) A/B/D sand laterals Value Density (ppg) 8~4 or as needed Plastic Viscostiy 12 - 19 (Ib/100 sf) Yield Point ~ $ _ 28 (cP Oil / Water Ratio 80 / 20 Electrical >600 Stability Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following 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 AAC 25.033(~; Not applicable: Application is not for an exploratory or stratigraphic test well. 1J-120 PERMIT IT Page 5 of 8 Printed: 28-Mar-07 "9 ~' € ~ ~ :e' ~ ~ ~~ ~ ~^` i . ,....~ ~_~ A~ation for Permit to Drill, Well 1J-120 Revision No.O Saved: 28-Mar-07 10.Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit fo 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 exploratory 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. 11.Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (li) for a we/l dri/led from an offshore p/atform, mobi/e bottom-founded structure, jack-up rig, or f/oating dri/ling vessel, an ana/ysis of seabed conditions as required by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following rtems, except for an item already on file with the commission and identified in the application: (12) evidence showing fhat the requirements of 20 AAC 25.025 {Bonding}have been met~ Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Dril1 must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 20" x 34" insulated conductor to +/- 108' RKB. Install landing ring on conductor. 2. Move in / rig up Doyon Rig 141. Install 21-1/4" Annular with 16" diverter line and function test. 3. Spud and directionally drill 13-1/2" hole to casing point at +/- 4,100' MD / 2,472' ND as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 10-3/4", 45.5#, L80, BTC casing to surface. Displace cement with mud and, pressure test casing to 2500 psi for 30 minutes and record results. Perform top job if required. 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's as described above in Section 3 above and test to 3,000 psi (annular preventer to 1500 psi). Notify AOGCC 24 hrs before test. 6. PU 9-7/8" bit and 6-3/4" drilling assembly, with MWD, LWD & PWD. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar. 7. Drill out cement and between 20' and 50' of new hole. If VersaPro Mineral Oil Base mud is intended for intermediate hole section, displace mud system over from water based system to mineral OBM following new hole drillout. Perform formation integrity test to leak ofF, recording results. (ECD's modeled to be less than 11.0 ppg) 8. Directionally drill to 7-5/8" casing point at 10,092' MD / 3,910' ND, the prognosis top of the A2 sand. 9. Run 7-5/8", 29.7# L80, BTC Mod casing to surface. Pump cement and displace with mud (top of cement to be 5,379' MD / 2,848' ND if Ugnu C formation is oil bearing. Top of cement to be 500 feet (MD) above shallowest oil bearing sand.). Pressure test casing to 3,000 psi for 30 minutes and record results. 10. Install wellhead x 7-5/8" packoff and test to 5000 psi. 11. Flush 10-3/4" x 7-5/8" annulus with water, followed by diesel. 1J-120 PERMIT IT Page 6 of 8 Pnnted: 28-Mar-07 .~ s, k:.~ ~ ~,..,~ ~ ~ ~ ~ ~ ~ 1~ k ~~~.i ~ ~ ~..~ ~ C~ A~ation for Permit to Drill, Well 1 J-120 Revision No.O Saved: 28-Mar-07 12. PU 6-3/4" PDC Bit and 4-3/4" drilling assembly, with MWD, and LWD logging tools. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the ffoat collar 13. Drill out cement and between 20' and 50' of new hole. Displace hole to lateral drilling mud. Pertorm formation integrity test to leak off, recording results. (Expected ECD's in 6-3/4" lateral modeled to be less than 12.5 ppg). 14. Directionally drill 6-3/4" hole to TD at +/- 16,3Z0' MD / 3,947' TVD as per directional plan. 15. POOH, back reaming out of lateral to 7-5/8" shoe. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 16. If injector, RU and run the USIT log from the shoe of the 7 5/8' casing to the shoe of the 10 3/4" casing. 17. PU and run 4-1/2" slotted liner. 18. Land liner, set (iner hanger @+/- 8,941' MD / 3,737' IVD. POOH. Note: Remaining operations are covered under the 17-120L1 Application for Permit to Drill, and are provided here for information only. ~d~_a~~ 19. Run and set Baker WindowMaster whipstock system, at window point of +/-8,841' MD / 3,720' TVD, the top of the B sand. 20. Mill 6-3/4" window. POOH. 21. Pick up 6-3/4" drilling assembly with LWD and MWD and PWD. RIH. 22. Drill to TD of B sand lateral at +/- 16,057' MD / 3,803' ND, as per directional plan. 23. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 24. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 25. PU and run 4-1/2" slotted liner. 26. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 27. Release hanger running tool. POOH. 28. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. POOH. Note: Remaining operations are covered under the 17-120L2 Application for Permit to Drill, and are provided here for information only. ~~--1_a`,,,~.~ 29. Run and set Baker WindowMaster whipstock system, at window point of +/- 8,341' MD / 3,626' ND, the top of the D sand. 30. Mill 6-3/4" window. POOH. 31. Pick up 6-3/4" drilling assembly with LWD and MWD and PWD. RIH. 32. Drill to TD of D sand lateral at +/- 16,050' MD / 3,737' TVD, as per directional plan. 33. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 34. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 35. PU and run 4-1/2" slotted liner. 36. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 1J-120 PERMIT IT Page 7 of 8 Printed: 28-Mar-07 ~ . < '! g '~~ i ~ ~ r „ . ~.... ~~ A~tion for Permit to Drill, Well 1J-120 Revision No.O Saved: 28-Mar-07 37. Release hanger running tool. POOH. 38. POOH, laying down drill pipe as required. 39. PU ESP completion with with backup gaslift as required and RIH to depth. Land tubing. Set BPV. 40. Nipple down BOPE, nipple up tree and test. Pull BPV. 41. Freeze protect well with diesel. 42. Set BPV and move rig off. 43. Rig up wire line unit. Pull BPV. 44. Circulate out well with diesel through the ESP 45. Set gas lift valves in mandrels. Operate well on gas lift until ESP facilities are ready. 46. Replace gas lift valves with blank dummy valves. 47. Place well on production with ESP. - 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1J 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 iJ Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement Loads and CemCADE Summary Attachment 4 Well Schematic Attachment 5% Mile Radius Scan 1J-120 PERMIT IT Page 8 of 8 Printed: 28-Mar-07 ~~~~~~~;°°~~~. 1J-1201 rillin~ Hazards S~nm (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 13-1/2" Open Hole / 10-3/4" Casing Interval Hazard Risk Level Miti ation Strate Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate i Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Driltreat. Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out Wellbore Collision with Moderate Adhere to Directional Program, Directional Existing wells Driller to update Traveling cylinder diagrams for every survey. 9-7/8" Open Hole / 7-5/8" Casing Interval Hazard Risk Level Miti ation Strate Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight, use weighted sweeps. Gas Hydrates Low Control drill, reduced pump rates, reduced ~ drilling fluid temperatures, additions of Driltreat. Stuck Pipe Low Good hole cleaning, PWD tools, pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Low ~ BOP training and drills, increased mud weight. Pressure Lost circulation Low Reduced pump rates, mud rheology, LCM Hole swabbing on trips Moderate . Trip speeds, proper hole filling (use of trip sheets), pumping out 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Miti ation Strate y Abnormal Reservoir Low . Stripping drills, shut-in drills, increased mud Pressure weight. Stuck Pipe Low Good hole cleaning, PWD tools, hole opener runs, decreased mud weight Lost Circulation Low Reduced pump rates, mud rheology, LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets),pumping out, backreaming Wellbore Collision with Moderate Adhere to Directional Program, Directional Existing wells Driller to update Traveling cylinder diagrams for every survey and monitor well to well proximities. 1J-120 Drilling Hazards Summary ~ ~~ ~~~ g~ prepared by Dennis D. Harlwig ~ ~ ~ ~ ~ ~~ ? ' 3/28/2007 1:59 PM • ° ~ • ~QI'~t~CCI~'l l ~ f 1 ~S Alaska \J Plan: 1J-120 (wp09) Sperry Drilling Services Proposal Report - Geographic 22 March, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-120 - Slot 1J-120 Plan 1J-120 Local Coordinate Origin: Centered on Well Plan 1J-120 - Slot 1J-120 Viewing Datum: oyon 141 Plan RKB Q 109.OOft (Doyon 141 (28+g1)) ' NDs to System: N North Reference: True ' Unit System: API - US Survey Feet ~~~..~..~ Gi~~i~i~.~f'M Sperry Drilling S~rvica: ~ ~4 . ~ ~ ~ ~ ~ ~~~.~~ ~.. ~ • HALLIBIJRTON Projed: KuparukRiverUni weicoernus ~~u-iao Site: Kuparuk 1J Pad cro~„~aiR~ec aioo Sp~rry G.yulny S~rvie~s Well: Plan iJ-120 +w-s ~Fr-w N~nn~ng ~n~ t~nm~a< io~m~d~ sia Wellbore: Plan 1J-120 ~?~x~ o~~ seasr,saoz ii8853.N1 70°IS'43.97iN ia9°~rzznw u-izo PI8f1: 1J-120 (WP09~ ,=ORMATIGN TGP DETn!LS T'JDPath TV~SS MDPaIh F,~-~-' ~ . , ~~ ~~~ ~ i 1;~5.58 1397.58 1654.70 P,.c.:,i 1558.11 1549.11 1897.55 T3 ~979.92 1870.92 2727.69 Y.:S C :2t5.98 2136.56 3470.05 Ca~~~~.~~~ - [5?889 2878.89 5879.06 U~.c~~.- S ~~~~Q 7:G552 319652 705839 Uynu ° \ 1~/ 7 _°E2.02 3273.02 7355.88 Uynu A 3477.34 3368.34 i734.15 K 73 SHL: 1875' FSL, 2357' FEL - Sec35-T11N-R10E \ / 9 se~27 97 35t8 97 8349.31 W Sak. C 0 ____ ~ ~ ' 1 66 3572 66 8609.58 W Sak .. ~723 03 3614,03 8859.04 W Sak 6 ; 65 3 35>6 33 91'IS?9 W Sak -~ ~° ~~ 2 52 715 92 9<7"+ i$ W k ^ ~ ,. 500 500 CASING DETAfLS No MD TVD NDSS Namc Si~e 1000 7000 1 1100.(q 2171.71 23G2.71 103/1" IO-3/J 2 10092.11 390H91 3%011.71 7 5/8" 7-5/8 3 16320.22 39~7J0 3838.10 J 1/2" J-I/2 1500 p~„sr- 1500 _'T3 ____ _ ___ _ _ z000 20GJ - K 15 _ _ _ _ _ _ 2e... '"~O • ~..,,,;_. ;~ ~ BHL @ 16320' MD, 3947' ND: 359' FSL, 1992' PEL- Sec24-T11N-R10E ~ c ~5~ ~ ~ 35p~_ _ _ 10 3!4" Surtace Csg. ~ 4700' MD, 2472 ND: 1416' FSL. 354'FWL - Sec36-T11N-R10E 1 " ' ' ' ' ~ ~ Begin Pump Tangent (d1 Int. Csg (8 10092 MD, 3920 ND: 587 FNL, 1874 FEL- Sec36-T11N-R 0E 8137' MD, 3577' ND ~ 5/8 ~ 4Sp0 c v ~ EnA Pump Tangenl ~ 8337' MD, 3825' TVD \ ~_-~o 5500 ~ _ ~......,. -, -- -- --------- ---- o ' $ ' ; _ - ~ ------ ------------- ------------------------------ ---------------- a ~ , n ° ti ' , ~ - ~'' / p 3, ~ -- e. . - ._._____ o". o___=' ;r,.~~_~ --- - _____,,..~oa__'_ ___,4'~_a__~__ 'K73_'::°~_.._______ _ ~_g___ ________________ , _________________ __ ----------------' --- ____________________________________'_________________~_____'_____'___ __ __y_______________ __°_________-~ ___ ___ ___ ___ _______ ___ __ ~ ~ J ' '-WSakD ' °' ' ~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _- _ _ _ ~ o o o o n a ~ ~ _ ~ _ _ _ _ _t _ _ _~'_ _o°_ _ _ ° __ _o_ __ ~__ _ o___ _ a° ° ° _ _ = iJ-720L2(wp091____ _ _ ~ ' a> _ ~ =v= _ _ _ _ _ _ _ _ _ ' _ _ _ _ _ _ _ _ _ _ _ _ _ . >'_"WSakC a __ __________'_____ '__'_' ._________.-_____,____ ~ , ~ ' ==_~ _=o = ° _ _ _ _ _ _ _ _ _ _ _ _ _ ' _ _ ' _ ' __`____ __ _____ _ _ _ _ _ _ _ _ _ _ _ _ r _ ~ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ?~ iJ-120 L7 (wp09) _ ' _ _ _ ______ ___' -'_____'____ _ ~_~,_.WSakB'____'___~ __ __ _ <_ _ _ _ ~ _ . . _ _ ___ ~ - - - - - 2 •r"l~ W Sak A4 ,' ~ i ~ 1J-120 (wp09) ~i, ~ 1J-720TO D(w 09) ~ °o o~ ~ i o 45G9 p p ~ ~ ` W Ssk A3 1J-120 Top B(wp09) i ~ 4 1 /2„ ~ ~ i W Sa~: R2 ~ ~ 5000 1J-120 MB A2 CP3 (0321/07) 1J-720 MB A2 CP6 (03/21/07 iJ-120 MB_A2;CP8 (0327/07 1J-120 MB_A2_CP4 (0321/07) ~y~ZO MB_A2_CP7 (03/21/07) ~~-~ZO MB_A2_Toe (0321/07 ~~.~:.~~ -;,'..J i:_ 0 5^_0 ~JCO 1~~7 .. _. -_.~ .;.7 ~=~~7 E0~0 4500 5000 5`:10 „i~ _~ ] -"~:i7 .-7 . `~~-7 __~,.~ 550 10G~~ ."_ Vertical Sedion a10.00° (1250 ~n) ~"~ ~Of10C0~11~~1~75 ~ o~i~~~AL ~ . HAL LIBURTON Project KuparukRiverUnit REFERENCEINFOR MATION WELLDETAllS PIan17-120 S ~ o ini S Site: KuparuklJPad CoroNinate(N/E)Rekrence.WeIlPI an1J~12J-&at1J120,TruaNOM ~~~ye~ q~~ p rry r n~ ~via~s Well: Plan 1 J-120 vert~i ~rvo~ a,rere~ce ooyo~ i a aian RKe ~ ios oon ~ooyo~ ia~ ~ze.ai~~ .ws .e~-w Nonn~ ~~~ ~~cu~a~ Lo~;~„ae sio~ Wellbore: Plan 1J-120 Abawre0 Depth Refererim: Doyu^ 1 ~ICUlationMethotl: Minimu 41 Pkn RKB ~ 109.0011(DOyon 141 (IB~81)) mC~rvaNre 000 O.W 5415688 U2 558853.50 7U°IS'J3.975N 149°3127.21 W II-120 Plan: 1 J-120 (w 09) ~~~x~u p vs~a I1-120 ( wp09) y(1(p ~ It_I'_ii,'.flin2l~~c~~~;:1/i~' ----__' " __'____Itlil.¢IF~20'MD.3')J7"IVI37i71'SI..1992'I~L'I.-Sa;2~4T11N-R105 '39J/ 8500 i!-r_or.m_a.z ces~o~rziro~ ------- - SOW u.i:nn~mnxcr'~tosrziro~ --'---- - - 75W 7000 ~J.~]i~t.r~,v cP~.,~~::_v~,- '----- 651q '. \ili .\' t I~-~ "~'. _ _ _ ' _' _" _ 6UW SSW a 5000 ~ `~' i5W + L ~ tap ', , ,.~~~ \fla ~' t~i~:~, ;'_I.,,- ________ ~ : ssoo s ~ ° N 3000 CASING DETAILS No MD TVD TVDss Namc $iie 1 JIWUO 2J71:71 2362]I 103/1" 103/a ~ ----- l i/%` In1. C'~g ~n. I~H)v2' MI).3v>_IY IVD~. >ST I~NI.. 187~' I'il,. k~?6TI IN-RIOE 2~~1 2 IW92.11 3909.91 ?RW.91 75/8" 7-5/8 3 16320.22 3917.10 38?8J 11R" 1-IR ?(NM) Il l_~~I ,Ii 1~•~ 7750 IJI~ . n~ i~~~+ "_____' IU(q I)-12oTopD1~'Wy '--"___ ____'~dRunpTengm13a833TR~ID.362S7VD 103/4'Siuf Csg.lo~41WMD,2472'TVD:~416'FSL,354'FWL-Sec36TI1N-RIUF. 13eginAunpTunga~ta~81lTMD.157T7VD SUO 1 ~-~00 0 $ ~ - ' ~ S ~ i g T M Azimuths to True North Magnetlc North~.23.66° -500 ~ ~ `~'o Magnetic Fieltl Streng[h~.576t5.5nT SFfl.:1875'FSL,23S7FEL-S~i>-TIIN-RIUP. ~ DipAngle:Ba.81° Date. 1/82007 -IUI)0 Model: BGGM2006 -1?IN) -2sW -2W0 -151q -IUUO -5~(1 U S00 I~W ISW 2W0 25pp 3IX)0 3500 1IX10 1500 Sp(q SSW 6000 6500 7WU 751q %U00 N50U Y(IW 95(p I~U110 I(ISIMI IIU00 II500 12(Nlfl 125U11 It11110 I'15110 I1111111 West(')/East(+) (1750 R/in) r ConocoPhiliips ~~ Canoc€~Phitlip-s Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level ' Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor = ~'~ _ =~ ~ '~ '~ti ~ Pfan 1J ~120 - Slot 1J-1~20 -~:~~~ .~~~„~~~~, ~~ _ ~, ,. ~~ ~ ~ ~ ~ ~ ~ ~ ~~ ~ ~~' ~~ ~ ~ ~ Well Position +N/-S 0.00 ft ~~ ~~~~ , ~«~ _ ~ Northing: 5,945,688.02 ft ~~~- ~~ ~;;~~-~ •~N~~ Latitude: 70° 15' 43.975" N +E/-W 0.00 ft Easting: 558,853.50 ft Longitude: 149° 31' 27.210" W Position Unce rtainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.OOft 3/22/2007 11:18:06AM Page 2 of 10 ,~ ~ rF~ ~ r*°.: s 4~w ¢ "~ ~ ~ ~ n~ ~ s ~ ~ '` . ~t COMPASS 2003.11 Build 48 ~ ~ 28.00 0.00 0.00 28.00 -81.00 ~_~.~. 0.00 __. n~~.~.~~~,.~ 0.00 ,,~=~~~,A~-~ 0.00 0.00 ~~ 0.00 ~ n~ 0.00 250.00 0.00 0.00 250.00 141.00 0.00 0.00 0.00 0.00 0.00 0.00 702.94 11.32 95.00 700.00 591.00 -3.89 44.44 2.50 2.50 0.00 95.00 1,644.68 48.94 99.86 1,500.00 1,391.00 -75.34 503.00 4.00 3.99 0.52 6.00 1,744.68 48.94 99.86 1,565.68 1,456.68 -88.25 577.29 0.00 0.00 0.00 0.00 2,145.82 69.00 99.86 1,771.40 1,662.40 -146.81 914.23 5.00 5.00 0.00 0.00 4,145.81 69.00 99.86 2,488.13 2,379.13 -466.53 2,753.81 0.00 0.00 0.00 0.00 4,287.48 73.25 99.86 2,533.95 2,424.95 -489.47 2,885.85 3.00 3.00 0.00 0.00 5,177.48 73.25 99.86 2,790.44 2,681.44 -635.40 3,725.50 0.00 0.00 0.00 0.00 8,137.30 75.94 6.36 3,576.50 3,467.50 897.31 5,759.79 3.05 0.09 -3.16 -88.29 8,337.30 75.94 6.36 3,625.07 3,516.07 1,090.13 5,781.28 0.00 0.00 0.00 0.00 8,341.01 75.99 6.25 3,625.97 3,516.97 1,093.70 5,781.68 3.08 1.25 -2.90 -66.04 8,633.26 80.47 358.55 3,685.66 3,576.66 1,379.26 5,793.49 3.00 1.53 -2.64 -60.13 8,840.65 80.47 358.55 3,720.00 3,611.00 1,583.72 5,788.32 0.00 0.00 0.00 0.00 8,845.08 80.52 358.67 3,720.73 3,611.73 1,588.08 5,788.21 3.00 1.27 2.76 65.00 9,842.95 80.52 358.67 3,885.01 3,776.01 2,572.08 5,765.41 0.00 0.00 0.00 0.00 9,992.14 85.00 358.69 3,903.80 3,794.80 2,720.00 5,762.00 3.00 3.00 0.01 0.23 10,099.82 88.22 358.91 3,910.16 3,801.16 2,827.45 5,759.75 3.00 2.99 0.20 3.88 10,149.74 88.22 358.91 3,911.71 3,802.71 2,877.34 5,758.80 0.00 0.00 0.00 0.00 10,215.88 88.84 358.67 3,913.41 3,804.41 2,943.45 5,757.40 1.00 0.93 -0.36 -21.13 11,415.88 88.84 358.67 3,937.70 3,828.70 4,142.88 5,729.55 0.00 0.00 0.00 0.00 11,503.72 89.72 358.67 3,938.81 3,829.81 4,230.68 5,727.52 1.00 1.00 0.00 0.26 13,415.02 89.72 358.67 3,948.20 3,839.20 6,141.45 5,683.29 0.00 0.00 0.00 0.00 13,522.12 94.00 358.67 3,944.72 3,835.72 6,248.43 5,680.81 4.00 4.00 0.00 -0.06 13,610.09 94.00 358.67 3,938.58 3,829.58 6,336.17 5,678.77 0.00 0.00 0.00 0.00 13,715.40 89.79 358.69 3,935.10 3,826.10 6,441.37 5,676.34 4.00 -4.00 0.02 179.72 14,315.40 89.79 358.69 3,937.30 3,828.30 7,041.21 5,662.63 0.00 0.00 0.00 0.00 14,326.01 89.68 358.69 3,937.35 3,828.35 7,051.82 5,662.38 1.00 -1.00 0.00 -179.88 14,915.23 89.68 358.69 3,940.60 3,831.60 7,640.87 5,648.91 0.00 0.00 0.00 0.00 14,937.45 89.46 358.67 3,940.77 3,831.77 7,663.09 5,648.40 1.00 -0.99 -0.11 -173.93 15,613.15 89.46 358.67 3,947.10 3,838.10 8,338.57 5,632.67 0.00 0.00 0.00 0.00 15,807.47 90.09 0.51 3,947.87 3,838.87 8,532.88 5,631.27 1.00 0.32 0.95 71.31 16,320.23 90.09 0.51 3,947.10 3,838.10 9,045.62 5,635.81 0.00 0.00 0.00 0.00 3/22/2007 11:18:06AM Page 3 of 10 COMPASS 2003.11 Build 48 ~ ~ ~ ~ ~ ~~ ~~i ~.,., ~ OI'14C0~'il~~[~5 Halliburton Company ~,~~(,,,,~~~„~~"~`~~ ~as~ Compass Proposal Report - Geographic g~.~ p~.~~fing Servicse Carrc~co~P~ti~lips Alaska ~ ~ Halliburton Company H:I~~.~..IBURTC~~V Compass Proposal Report - Geographic g~~,y p~~iing Barvicss 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5,945,688.02 ~ 558,853.50 ~ 0.00 0.00 SHL: 1875' FSL, 2357 ' FEL - Sec35-T11 N-R10E ' 100.00 0.00 0.00 100.00 -9.00 0.00 0.00 5,945,688.02 558,853.50 0.00 0.00 200.00 0.00 0.00 200.00 91.00 0.00 0.00 5,945,688.02 558,853.50 0.00 0.00 250.00 0.00 0.00 250.00 141.00 0.00 0.00 5,945,688.02 558,853.50 0.00 0.00 300.00 1.25 95.00 300.00 191.00 -0.05 0.54 5,945,687.98 558,854.04 2.50 -0.05 400.00 3.75 95.00 399.89 290.89 -0.43 4.89 5,945,687.63 558,858.39 2.50 -0.43 500.00 6.25 95.00 499.50 390.50 -1.19 13.57 5,945,686.94 558,867.08 2.50 -1.19 600.00 8.75 95.00 598.64 489.64 -2.32 26.57 5,945,685.90 558,880.09 2.50 -2.32 700.00 11.25 95.00 697.11 588.11 -3.84 43.87 5,945,684.53 558,897.39 2.50 -3.84 702.94 11.32 95.00 700.00 591.00 -3.89 44.44 5,945,684.48 558,897.97 2.50 -3.89 800.00 15.19 96.55 794.45 685.45 -6.17 66.58 5,945,682.37 558,920.12 4.00 -6.17 900.00 19.18 97.50 889.97 780.97 -9.81 95.89 5,945,678.96 558,949.46 4.00 -9.81 1,000.00 23.17 98.14 983.20 874.20 -14.74 131.67 5,945,674.31 558,985.27 4.00 -14.74 1,100.00 27.17 98.59 1,073.68 964.68 -20.94 173.74 5,945,668.44 559,027.38 4.00 -20.94 1,200.00 31.17 98.94 1,160.99 1051.99 -28.37 221.89 5,945,661.39 559,075.59 4.00 -28.37 1,300.00 35.16 99.21 1,244.68 1135.68 -37.01 275.90 5,945,653.17 559,129.66 4.00 -37.01 1,400.00 39.16 99.44 1,324.36 1215.36 -46.80 335.50 5,945,643.85 559,189.32 4.00 -46.80 1,500.00 43.16 99.63 1,399.63 1290.63 -57.70 400.39 5,945,633.45 559,254.29 4.00 -57.70 1,600.00 47.16 99.79 1,470.13 1361.13 -69.67 470.26 5,945,622.04 559,324.25 4.00 -69.67 1,644.68 48.94 99.86 1,500.00 1391.00 -75.34 503.00 5,945,616.62 559,357.03 4.00 -75.34 1,654.70 48.94 99.86 1,506.58 1397.58 -76.63 510.45 5,945,615.39 559,364.48 0.00 -76.63 Pfrost 1,700.00 48.94 99.86 1,536.33 1427.33 -82.48 544.10 5,945,609.80 559,398.18 0.00 -82.48 1,744.68 48.94 99.86 1,565.68 1456.68 -88.25 577.29 5,945,604.29 559,431.41 0.00 -88.25 1,800.00 51,71 99.86 1,600.99 1491.99 -95.54 619.24 5,945,597.33 559,473.41 5.00 -95.54 1,897.55 56,59 99.86 1,658.11 1549.11 -109.07 697.12 5,945,584.41 559,551.38 5.00 -109.07 T3 1,900.00 56.71 99.86 1,659.46 1550.46 -109.42 699.13 5,945,584.07 559,553.40 4.98 -109.42 2,000.00 61.71 99.86 1,710.63 1601.63 -124.13 783.74 5,945,570.03 559,638.11 5.00 -124.13 2,100.00 66.71 99.86 1,754.13 1645.13 -139.54 872.42 5,945,555.31 559,726.90 5.00 -139.54 2,145.82 69.00 99.86 1,771.40 1662.40 -146.81 914.23 5,945,548.38 559,768.76 5.00 -146.81 2,200.00 69.00 99.86 1,790.81 1681.81 -155.47 964.07 5,945,540.10 559,818.66 0.00 -155.47 2,300.00 69.00 99.86 1,826.65 1717.65 -171.46 1,056.05 5,945,524.84 559,910.75 0.00 -171.46 2,400.00 69.00 99.86 1,862.49 1753.49 -987.44 1,148.03 5,945,509.57 560,002.85 0.00 -187.44 2,500.00 69.00 99.86 1,898.32 1789.32 -203.43 1,240.01 5,945,494.31 560,094.94 0.00 -203.43 2,600.00 69.00 99.86 1,934.16 1825.16 -219.41 1,331.98 5,945,479.04 560,187.03 0.00 -219.41 2,700.00 69.00 99.86 1,970.00 1861.00 -235.40 1,423.96 5,945,463.78 560,279.12 0.00 -235.40 2,727.69 69.00 99.86 1,979.92 1870.92 -239.83 1,449.43 5,945,459.55 560,304.62 0.00 -239.83 K15 2,800.00 69.00 99.86 2,005.83 1896.83 -251.39 1,515.94 5,945,448.51 560,371.22 0.00 -251.39 2,900.00 69.00 99.86 2,041.67 1932.67 -267.37 1,607.92 5,945,433.25 560,463.31 0.00 -267.37 3,000.00 69.00 99.86 2,077.51 1968.51 -283.36 1,699.90 5,945,417.98 560,555.40 0.00 -283.36 3,100.00 69.00 99.86 2,113.35 2004.35 -299.34 1,791.88 5,945,402.72 560,647.49 0.00 -299.34 3,200.00 69.00 99.86 2,149.18 2040.18 -315.33 1,883.86 5,945,387.45 560,739.59 0.00 -315.33 3,300.00 69.00 99.86 2,185.02 2076.02 -331.31 1,975.84 5,945,372.19 560,831.68 0.00 -331.31 3/22~2007 11:18:06AM Page 4 of 10 COMPASS 2003.11 Build 48 ~ ~C\~ t,~~~~~ ~~a~. s COI'10C0~"1I~~IpS Alaska 3,400.00 69.00 99.86 2,220.86 2111.86 -347.30 2,067.82 5,945,356.92 560,923.77 0.00 -347.30 3,470.05 69.00 99.86 2,245.96 2136.96 -358.50 2,132.25 5,945,346.23 560,988.28 0.00 -358.50 Casing Pt 3,500.00 69.00 99.86 2,256.69 2147.69 -363.29 2,159.80 5,945,341.66 561,015.86 0.00 -363.29 3,600.00 69.00 99.86 2,292.53 2183.53 -379.27 2,251.78 5,945,326.39 561,107.96 0.00 -37927 3,700.00 69.00 99.86 2,328.37 2219.37 -395.26 2,343.76 5,945,311.13 561,200.05 0.00 ,-395.26 3,800.00 69.00 99.86 2,364.20 2255.20 -411.24 2,435.74 5,945,295.86 561,292.14 0.00 -411.24 3,900.00 69.00 99.86 2,400.04 2291.04 -427.23 2,527.71 5,945,280.60 561,384.23 0.00 -427.23 4,000.00 69.00 99.86 2,435.88 2326.88 -443.22 2,619.69 5,945,265.33 561,476.33 0.00 -443.22 4,100.00 69.00 99.86 2,471.71 2362.71 -459.20 2,711.67 5,945,250.07 561,568.42 0.00 -459.20 10 3/4" Surtace Csg. @ 4100' MD, 2472' ND: 1416' FSL, 354'FWL - Sec36-T11 N-R10E -10 314" 4,145.81 69.00 99.86 2,488.13 2379.13 -466.53 2,753.81 5,945,243.08 561,610.61 0.00 -466.53 4,200.00 70.63 99.86 2,506.83 2397.83 -475.23 2,803.92 5,945,234.76 561,660.78 3.00 -475.23 4,287.48 73.25 99.86 2,533.95 2424.95 -489.47 2,885.85 5,945,221.16 561,742.81 3.00 -489.47 4,300.00 73.25 99.86 2,537.56 2428.56 -491.53 2,897.66 5,945,219.20 561,754.64 0.00 -491.53 4,400.00 73.25 99.86 2,566.38 2457.38 -507.92 2,992.00 5,945,203.54 561,849.10 0.00 -507.92 4,500.00 73.25 99.86 2,595.20 2486.20 -524.32 3,086.35 5,945,187.89 561,943.55 0.00 -524.32 4,600.00 73.25 99.86 2,624.02 2515.02 -540.72 3,180.69 5,945,172.23 562,038.01 0.00 -540.72 4,700.00 73.25 99.86 2,652.84 2543.84 -557.11 3,275.03 5,945,156.57 562,132.47 0.00 -557.11 4,800.00 73.25 99.86 2,681.66 2572.66 -573.51 3,369.38 5,945,140.92 562,226.93 0.00 -573.51 4,900.00 73.25 99.86 2,710.48 2601.48 -589.91 3,463.72 5,945,125.26 562,321.39 0.00 -589.91 5,000.00 73.25 99.86 2,739.30 2630.30 -606.30 3,558.06 5,945,109.60 562,415.85 0.00 -606.30 5,100.00 73.25 99.86 2,768.12 2659.12 -622.70 3,652.40 5,945,093.94 562,510.31 0.00 -622.70 5,177.48 73.25 99.86 2,790.44 2681.44 -635.40 3,725.50 5,945,081.81 562,583.49 0.00 -635.40 5,200,00 73.27 99.15 2,796.93 2687.93 -638.97 3,746.77 5,945,078.42 562,604.79 3.02 -638.97 5,300.00 73.36 95.99 2,825.64 2716.64 -651.58 3,841.71 5,945,066.55 562,699.82 3.03 -651.58 5,400,00 73.45 92.83 2,854.20 2745.20 -658.95 3,937.25 5,945,059.93 562,795.41 3.03 -658.95 5,500.00 73.54 89.67 2,882.60 2773.60 -661.04 4,033.10 5,945,058.58 562,891.26 3.03 -661.04 5,600.00 73.63 86.51 2,910.85 2801.85 -657.85 4,128.96 5,945,062.53 562,987.08 3.03 -657.85 5,700.00 73.73 83.35 2,938.95 2829.95 -649.37 4,224.55 5,945,071.75 563,082.59 3.03 -649.37 5,800.00 73.82 80.20 2,966.90 2857.90 -635.63 4,319.56 5,945,086.23 563,177.48 3.03 -635.63 5,879.06 73.89 77.70 2,988.89 2879.89 -621.07 4,394.09 5,945,101.37 563,251.89 3.04 -621.07 Ugnu C ~ ~ Halliburton Company Compass Proposal Report - Geographic ~A,~.~.t..18~i~TC~N 8perry Driflit~g Ssrvicss 5,900.00 73.91 77.04 2,994.70 2885.70 -616.67 4,413.72 5,945,105.92 563,271.48 3.03 -616.67 6,000.00 74.00 73.88 3,022.34 2913.34 -592.54 4,506.73 5,945,130,77 563,364.29 3.04 -592.54 6,100.00 74.09 70.72 3,049.83 2940.83 -563.31 4,598.31 5,945,160,72 563,455.63 3.04 -563.31 6,200.00 74.18 67.56 3,077.16 2968.16 -529.06 4,688.19 5,945,195,67 563,545.23 3.04 -529.06 6,300.00 74.27 64.40 3,104.35 2995.35 -489.89 4,776.08 5,945,235,52 563,632.80 3.04 -489.89 6,400.00 74.36 61.24 3,131.38 3022.38 -445.92 4,861.71 5,945,280,16 563,718.08 3.04 -445.92 6,500.00 74.45 58.08 3,158.26 3049.26 -397.27 4,944.83 5,945,329.45 563,800.81 3.04 -397.27 6,600.00 74.55 54.92 3,184.98 3075.98 -344.09 5,025.18 5,945,383.24 563,880.73 3.05 -344.09 6,700.00 74.64 51.76 3,211.55 3102.55 -286.54 5,102.51 5,945,441.39 563,957.60 3.05 -286.54 6,800.00 74.73 48.61 3,237.97 3128.97 -224.80 5,176.58 5,945,503.71 564,031.18 3.05 -224.80 6,900.00 74.82 45.45 3,264.23 3155.23 -159.03 5,247.17 5,945,570.02 564,101.25 3.05 -159.03 7,000.00 74.91 42.29 3,290.35 3181.35 -89.44 5,314.05 5,945,640.12 564,167.58 3.05 -89.44 3/22/2007 11:18:06AM Page 5 of 10 COMPASS 2003.11 Build 48 ~~~~~~ ~. ~ ~ 7,058.39 74.96 40.44 3,305.52 3196.52 -47.13 5,351.31 5,945,682.72 564,204.50 3.05 -47.13 Ugnu B 7,100.00 75.00 39.13 3,316.30 3207.30 -16.25 5,377.03 5,945,713.80 564,229.97 3.05 -16.25 7,200.00 75.09 35.97 3,342.11 3233.11 60.34 5,435.90 5,945,790.84 564,288.24 3.05 60.34 7,300.00 75.18 32.81 3,367.76 3258.76 140.09 5,490.49 5,945,871.01 564,342.20 3.05 140.09 7,355.86 75.24 31.05 3,382.02 3273.02 185.93 5,519.05 5,945,917.06 564,370.39 3.06 185.93 Ugnu A 7,400.00 75.27 29.65 3,393.26 3284.26 222.76 5,540.61 5,945,954.06 564,391.67 3.05 222.76 7,500.00 75.36 26.49 3,418.60 3309.60 308.11 5,586.13 5,946,039.75 564,436.51 3.06 308.11 7,600.00 75.46 23.33 3,443.79 3334.79 395.87 5,626.89 5,946,127.81 564,476.58 3.06 395.87 7,700.00 75.55 20.18 3,468.83 3359.83 485.78 5,662.77 5,946,217.99 564,511.75 3.06 485.78 7,734.15 75.58 19.10 3,477.34 3368.34 516.93 5,673.88 5,946,249.22 564,522.62 3.06 516.93 K13 7,800.00 75.64 17.02 3,493.71 3384.71 577.56 5,693.65 5,946,310.01 564,541.91 3.06 577.56 7,900.00 75.73 13.86 3,518.44 3409.44 670.95 5,719.43 5,946,403.59 564,566.97 3.06 670.95 8,000.00 75.82 10.70 3,543.01 3434.01 765.66 5,740.04 5,946,498.44 564,586.83 3.06 765.66 8,100.00 75.91 7.54 3,567.43 3458.43 861.39 5,755.41 5,946,594.28 564,601.45 3.06 861.39 8,137.30 75.94 6.36 3,576.50 3467.50 897.31 5,759.79 5,946,630.23 564,605.54 3.07 897.31 Begin Pum p Tangent @ 8137' MD, 3577' ND 8,200.00 75.94 6.36 3,591.73 3482.73 957.75 5,766.52 5,946,690.72 564,611.81 0.00 957.75 8,300.00 75.94 6.36 3,616.01 3507.01 1,054.16 5,777.27 5,946,787.20 564,621.80 0.00 1,054.16 8,337.30 75.94 6.36 3,625.07 3516.07 1,090.13 5,781.28 5,946,823.19 564,625.53 0.00 1,090.13 End Pump Tangent ae 8337' MD, 3625' ND 8,341.01 75.99 6.25 3,625.97 3516.97 1,093.70 5,781.68 5,946,826.77 564,625.90 3.08 1,093.70 8,342.04 76.01 6.23 3,626.22 3517.22 1,094.70 5,781.78 5,946,827.76 564,626.00 3.00 1,094.70 1J-120 Top D (wp09) 8,349.31 76.12 6.03 3,627.97 3518.97 1,101.71 5,782.54 5,946,834.78 564,626.69 3.00 1,101.71 W Sak D 8,400.00 76.88 4.68 3,639.81 3530.81 1,150.78 5,787.13 5,946,883.89 564,630.91 3.00 1,150.78 8,500.00 78.40 2.03 3,661.22 3552.22 1,248.29 5,792.84 5,946,981.42 564,635.85 3.00 1,248.29 8,600.00 79.95 359.42 3,680.00 3571.00 1,346.49 5,794.08 5,947,079.62 564,636.32 3.00 1,346.49 8,609.58 80.10 359.17 3,681.66 3572.66 1,355.92 5,793.96 5,947,089.05 564,636.13 3.01 1,355.92 W Sak C 8,633.26 80.47 358.55 3,685.66 3576.66 1,379.26 5,793.49 5,947,112.38 564,635.48 3.00 1,379.26 8,700.00 80.47 358.55 3,696.71 3587.71 1,445.05 5,791.83 5,947,178.16 564,633.30 0.00 1,445.05 8,800.00 80.47 358.55 3,713.27 3604.27 1,543.64 5,789.33 5,947,276.71 564,630.04 0.00 1,543.64 8,840.65 80.47 358.55 3,720.00 3611.00 1,583.72 5,788.32 5,947,316.78 564,628.71 0.00 1,583.72 1J-120 Top B (wp09) 8,845.08 80.52 358.67 3,720.73 3611.73 1,588.08 5,788.21 5,947,321.14 564,628.57 3.00 1,588.08 8,859.04 80.52 358.67 3,723.03 3614.03 1,601.86 5,787.89 5,947,334.91 564,628.14 0.00 1,601.86 W Sak B 8,900.00 80.52 358.67 3,729.77 3620.77 1,642.24 5,786.96 5,947,375.28 564,626.89 0.00 1,642.24 9,000.00 80.52 358.67 3,746.24 3637.24 1,740.55 5,784.67 5,947,473.86 564,623.84 0.00 1,740.85 3/22/2007 11:18:06AM Page 6 of 10 COMPASS 2003.11 Build 48 ~tt~~'~~~,.~ ~ Hailiburton Company ~~~,.I~[E~3UIRT~~'11 ~~~P~~~~~~5 Compass Proposal Report - Geographic $ p~~~i~ ~~~; Alaska ~'Y g ~ ~ Ct31"10t ~'11~~1~7-5 Alaska Halliburton Company Compass Proposal Report - Geographic ~ 1~-~:A ~..1..1 l~ [.1 f~ TID ~ V Sperry O~iliing Servic~s 9,100.00 80.52 358.67 3,762.70 3653.70 1,839.46 5,782.39 5,947,572.44 564,620.78 0.00 1,839.46 9,115.99 80.52 358.67 3,765.33 3656.33 1,855.22 5,782.02 5,947,588.20 564,620.29 0.00 1,855.22 W Sak A4 9,200.00 80.52 358.67 3,779.16 3670.16 1,938.07 5,780.10 5,947,671.02 564,617.72 0.00 1,938.07 9,300.00 80.52 358.67 3,795.62 3686.62 2,036.68 5,777.82 5,947,769.60 564,614.67 0.00 2,036.68 9,400.00 80.52 358.67 3,812.09 3703.09 2,135.29 5,775.53 5,947,868.17 564,611.61 0.00 2,135.29 9,477.95 80.52 358.67 3,824.92 3715.92 2,212.16 5,773.75 5,947,945.02 564,609.23 0.00 2,212.16 W Sak A3 9,500.00 80.52 358.67 3,828.55 3719.55 2,233.90 5,77324 5,947,966.75 564,608.56 0.00 2,233.90 9,600.00 80.52 358.67 3,845.01 3736.01 2,332.51 5,770.96 5,948,065.33 564,605.50 0.00 2,332.51 9,700.00 80.52 358.67 3,861.48 3752.48 2,431.11 5,768.67 5,948,163.91 564,602.44 0.00 2,431.11 9,800.00 80.52 358.67 3,877.94 3768.94 2,529.72 5,766.39 5,948,262.49 564,599.39 0.00 2,529.72 9,842.95 80.52 358.67 3,885.01 3776.01 2,572.08 5,765.41 5,948,304.83 564,598.07 0.00 2,572.08 9,900.00 82.23 358.68 3,893.56 3784.56 2,628.46 5,764.10 5,948,361.20 564,596.33 3.00 2,628.46 9,992.14 85.00 358.69 3,903.80 3794.80 2,720.00 5,762.00 5,948,452.71 564,593.51 3.00 2,720.00 10,000.00 85.23 358.71 3,904.47 3795.47 2,727.83 5,761.82 5,948,460.53 564,593.27 2.98 2,727.83 10,092.14 87.99 358.89 3,909.91 3800.91 2,819.78 5,759.90 5,948,552.46 564,590.63 3.00 2,819.78 7 5/8" Int. Csg @ 10092' MD, 3920' ND: 587' FNL, 1874' FEL - Sec36-T11 N-R10E - 7 5/8" 10,099.82 88.22 358.91 3,910.16 3801.16 2,827.45 5,759.75 5,948,560.13 564,590.42 3.00 2,827.45 10,100.00 88.22 358.91 3,910.17 3801.17 2,827.63 5,759.74 5,948,560.31 564,590.42 0.00 2,827.63 10,149.74 88.22 358.91 3,911.71 3802.71 2,877.34 5,758.80 5,948,610.00 564,589.08 0.00 2,877.34 10,200.00 88.69 358.73 3,913.06 3804.06 2,927.57 5,757.76 5,948,660.22 564,587.65 1.00 2,927.57 10,215.88 88.84 358.67 3,913.41 3804.41 2,943.45 5,757.40 5,948,676.09 564,587.17 1.00 2,943.45 10,300.00 88.84 358.67 3,915.11 3806.11 3,027.52 5,755.45 5,948,760.14 564,584.56 0.00 3,027.52 10,400.00 88.84 358.67 3,917.13 3808.13 3,127.48 5,753.13 5,948,860.06 564,581.46 0.00 3,127.48 10,500.00 88.84 358.67 3,919.16 3810.16 3,227.43 5,750.81 5,948,959.99 564,578.36 0.00 3,227.43 10,600.00 88.84 358.67 3,921.18 3812.18 3,327.38 5,748.49 5,949,059.91 564,575.25 0.00 3,327.38 10,700.00 88.84 358.67 3,923.21 3814.21 3,427.33 5,746.17 5,949,159.83 564,572.15 0.00 3,427.33 10,800.00 88.84 358.67 3,925.23 3816.23 3,527.29 5,743.85 5,949,259.75 564,569.05 0.00 3,527.29 10,900.00 88.84 358.67 3,927.26 3818.26 3,627.24 5,741.52 5,949,359.67 564,565.95 0.00 3,627.24 11,000.00 88.84 358.67 3,929.28 3820.28 3,727.19 5,739.20 5,949,459.59 564,562.85 0.00 3,727.19 11,100.00 88.84 358.67 3,931.31 3822.31 3,827.15 5,736.88 5,949,559.52 564,559.75 0.00 3,827.15 11,200.00 88.84 358.67 3,933.33 3824.33 3,927.10 5,734.56 5,949,659.44 564,556.65 0.00 3,927.10 11,218.79 88.84 358.67 3,933.71 3824.71 3,945.88 5,734.13 5,949,678.21 564,556.06 0.00 3,945.88 W Sak A2 11,300.00 88.84 358.67 3,935.35 3826.35 4,027.05 5,732.24 5,949,759.36 564,553.54 0.00 4,027.05 11,400.00 88.84 358.67 3,937.38 3828.38 4,127.00 5,729.92 5,949,859.28 564,550.44 0.00 4,127.00 11,415.88 88.84 358.67 3,937.70 3828.70 4,142.88 5,729.55 5,949,875.15 564,549.95 0.00 4,142.88 1J-120 MB_A2_CP3 (03121107) 11,500.00 89.68 358.67 3,938.79 3829.79 4,226.96 5,727.60 5,949,959.21 564,547.34 1.00 4,226.96 11,503.72 89.72 358.67 3,938.81 3829.81 4,230.68 5,727.52 5,949,962.93 564,547.23 1.00 4,230.68 11,600.00 89.72 358.67 3,939.28 3830.28 4,326.94 5,725.29 5,950,059.15 564,544.25 0.00 4,326.94 11,700.00 89.72 358.67 3,939.77 3830.77 4,426.91 5,722.98 5,950,159.10 564,541.15 0.00 4,426.91 11,800.00 89.72 358.67 3,940.26 3831.26 4,526.88 5,720.66 5,950,259,04 564,538.06 0.00 4,526.88 11,900.00 89.72 358.67 3,940.75 3831.75 4,626.85 5,718.35 5,950,358.98 564,534.96 0.00 4,626.85 12,000.00 89.72 358.67 3,941.24 3832.24 4,726.82 5,716.03 5,950,458.92 564,531.87 0.00 4,726.82 3/22/2007 11:18:06AM Page 7 of 10 COMPASS 2003.11 Build 48 ~ , ~- ~- , -' ` ~ ~4" ~ ~ ~...~ Y4r ~` 3ul~ ~~ ~~ ~ l~Ai"K)CO~'1i~~lp-S Fdaska Halliburton Company Compass Proposal Report - Geographic • ~"'~/Q~..L~~~~Y~~ 8pst~ry Dr~lEing ~arvices ~ ~ - 1 J 120 09 ~~ ' ~~ ~ ~ ~ ~ ~ ~ ~~ ,~~m ~ ~ ~ , _ ~ ~ ~~ ~~~ ~ ~;~ MN ` ~ ~ ~ ~ ~ -- /~ ;; '` ~° ~ r - _ ' A ~'s~~ ~ ' ~ i -- = r - - £_ - ` _ - _ - ~ _ -- ~s ;~ ~, ~ ` , - i . .m- ~ . ? ' ' _ _ ~ ~ - ~ i i L _ I _: ~ ~ ~ ~ ,w „ : i i i ~:i .i a , , i .. = ; ~ ;.r.... - ~ ;:. a~ ~ `~ ~ .~., i~ ~ u..' . .~ . .. . 7'`~ ~._ ~ ~~' ... . . -....... tl~ 12,100.00 89.72 358.67 3,941.74 3832.74 4,826.80 5,713.72 5,950,558.86 564,528.77 0.00 4,826.80 12,200.00 89.72 358.67 3,942.23 3833.23 4,926.77 5,711.40 5,950,658.80 564,525.68 0.00 4,926.77 12,300.00 89.72 358.67 3,942.72 3833.72 5,026.74 5,709.09 5,950,758.74 564,522.58 0.00 5,026.74 12,400.00 89.72 358.67 3,943.21 3834.21 5,126.71 5,706.78 5,950,858.68 564,519.49 0.00 5,126.71 12,500.00 89.72 358.67 3,943.70 3834.70 5,226.68 5,704.46 5,950,958.63 564,516.39 0.00 5,226.68 12,600.00 89.72 358.67 3,944.19 3835.19 5,326.66 5,702.15 5,951,058.57 564,513.30 0.00 5,326.66 12,700.00 89.72 358.67 3,944.69 3835.69 5,426.63 5,699.83 5,951,158.51 564,510.20 0.00 5,426.63 12,800.00 89.72 358.67 3,945.18 3836.18 5,526.60 5,697.52 5,951,258.45 564,507.11 0.00 5,526.60 12,900.00 89.72 358.67 3,945.67 3836.67 5,626.57 5,695.21 5,951,358.39 564,504.01 0.00 5,626.57 13,000.00 89.72 358.67 3,946.16 3837.16 5,726.54 5,692.89 5,951,458.33 564,500.92 0.00 5,726.54 13,100.00 89.72 358.67 3,946.65 3837.65 5,826.52 5,690.58 5,951,558.27 564,497.82 0.00 5,826.52 13,200.00 89.72 358.67 3,947.14 3838.14 5,926.49 5,688.26 5,951,658.21 564,494.73 0.00 5,926.49 13,300.00 89.72 358.67 3,947.63 3838.63 6,026.46 5,685.95 5,951,758.16 564,491.63 0.00 6,026.46 13,400.00 89.72 358.67 3,948.13 3839.13 6,126.43 5,683.63 5,951,858.10 564,488.53 0.00 6,126.43 13,415.02 89.72 358.67 3,948.20 3839.20 6,141.45 5,683.29 5,951,873.11 564,488.07 0.00 6,141.45 1J-120 MB_A2_CP4 (03/21l07) 13,500.00 93.12 358.67 3,946.10 3837.10 6,226.37 5,681.32 5,951,958.00 564,485.44 4.00 6,226.37 13,522.12 94.00 358.67 3,944.72 3835.72 6,248.43 5,680.81 5,951,980.06 564,484.75 4.01 6,248.43 13,600.00 94.00 358.67 3,939.29 3830.29 6,326.11 5,679.00 5,952,057.71 564,482.34 0.00 6,326.11 13,610.09 94.00 358.67 3,938.58 3829.58 6,336.17 5,678.77 5,952,067.77 564,482.03 0.00 6,336.17 13,700.00 90.41 358.69 3,935.13 3826.13 6,425.98 5,676.70 5,952,157.55 564,479.26 4.00 6,425.98 13,715.40 89.79 358.69 3,935.10 3826.10 6,441.37 5,676.34 5,952,172.93 564,478.78 4.01 6,441.37 13,800.00 89.79 358.69 3,935.41 3826.41 6,525.95 5,674.41 5,952,257.49 564,476.19 0.00 6,525.95 13,900.00 89.79 358.69 3,935.78 3826.78 6,625.92 5,672.12 5,952,357.43 564,473.12 0.00 6,625.92 14,000.00 89.79 358.69 3,936.14 3827.14 6,725.89 5,669.84 5,952,457.37 564,470.05 0.00 6,725.89 14,100.00 89.79 358.69 3,936.51 3827.51 6,825.87 5,667.55 5,952,557.32 564,466.99 0.00 6,825.87 14,200.00 89.79 358.69 3,936.88 3827.88 6,925.84 5,665.26 5,952,657.26 564,463.92 0.00 6,925.84 14,300.00 89.79 358.69 3,937.24 3828.24 7,025.81 5,662.98 5,952,757.20 564,460.85 0.00 7,025.81 14,315.40 89.79 358.69 3,937.30 3828.30 7,041.21 5,662.63 5,952,772.59 564,460.38 0.00 7,041.21 1J-120 MB_A2_CP6 (03/21/07) 14,326.01 89.68 358.69 3,937.35 3828.35 7,051.82 5,662.38 5,952,783.20 564,460.05 1.00 7,051.82 14,400.00 89.68 358.69 3,937.76 3828.76 7,125.79 5,660.69 5,952,857.14 564,457.78 0.00 7,125.79 14,500.00 89.68 358.69 3,938.31 3829.31 7,225.76 5,658.41 5,952,957.09 564,454.72 0.00 7,225.76 14,600.00 89.68 358.69 3,938.86 3829.86 7,325.73 5,656.12 5,953,057.03 564,451.65 0.00 7,325.73 14,700.00 89.68 358.69 3,939.41 3830.41 7,425.70 5,653.83 5,953,156.97 564,448.58 0.00 7,425.70 14,800.00 89.68 358.69 3,939.96 3830.96 7,525.68 5,651.55 5,953,256.91 564,445.51 0.00 7,525.68 14,900.00 89.68 358.69 3,940.52 3831.52 7,625.65 5,649.26 5,953,356.85 564,442.45 0.00 7,625.65 14,915.23 89.68 358.69 3,940.60 3831.60 7,640.87 5,648.91 5,953,372.07 564,441.98 0.00 7,640.87 1J-120 MB_A2_CP7 (03/21/07) 14,937.45 89.46 358.67 3,940.77 3831.77 7,663.09 5,648.40 5,953,394.28 564,441.29 1.00 7,663.09 15,000.00 89.46 358.67 3,941.35 3832.35 7,725.62 5,646.94 5,953,456.79 564,439.35 0.00 7,725.62 15,100.00 89.46 358.67 3,942.29 3833.29 7,825.59 5,644.61 5,953,556.73 564,436.24 0.00 7,825.59 15,200.00 89.46 358.67 3,943.23 3834.23 7,925.56 5,642.29 5,953,656.67 564,433.13 0.00 7,925.56 15,300.00 89.46 358.67 3,944.16 3835.16 8,025.52 5,639.96 5,953,756.61 564,430.02 0.00 8,025.52 15,400.00 89.46 358.67 3,945.10 3836.10 8,125.49 5,637.63 5,953,856.54 564,426.92 0.00 8,125.49 15,500.00 89.46 358.67 3,946.04 3837.04 8,225.46 5,635.31 5,953,956.48 564,423.81 0.00 8,225.46 15,600.00 89.46 358.67 3,946.98 3837.98 8,325.43 5,632.98 5,954,056.42 564,420.70 0.00 8,325.43 3/22/2007 11:18:O6AM Page 8 of 10 COMPASS 2003.11 Build 48 ~~~ ~~~~~i~ ! • 15,613.15 89.46 358.67 3,947.10 3838.10 8,338.57 5,632.67 5,954,069.56 564,420.29 0.00 5,338.57 1J-120 MB_A2_CP8 (03l21/07) 15,700.00 89.74 359.49 3,947.70 3838.70 8,425.41 5,631.27 5,954,156.37 564,418.21 1.00 8,425.41 15,800.00 90.06 0.44 3,947.88 3838.88 8,525.41 5,631.21 5,954,256.36 564,417.37 1.00 8,525.41 15,807.47 90.09 0.51 3,947.87 3838.87 8,532.88 5,631.27 5,954,263.83 564,417.37 1.00 8,532.88 15,900.00 90.09 0.51 3,947.73 3838.73 8,625.41 5,632.09 5,954,356.35 564,417.47 0.00 8,625.41 16,000.00 90.09 0.51 3,947.58 3838.58 8,725.40 5,632.97 5,954,456.34 564,417.57 0.00 8,725.40 16,100.00 90.09 0.51 3,947.43 3838.43 8,825.40 5,633.86 5,954,556.33 564,417.67 0.00 8,825.40 16,200.00 90.09 0.51 3,947.28 3838.28 8,925.39 5,634.74 5,954,656.32 564,417.78 0.00 8,925.39 16,300.00 90.09 0.51 3,947.13 3838.13 9,025.39 5,635.63 5,954,756.31 564,417.88 0.00 9,025.39 16,320.23 90.09 0.51 3,947.10 3838.10 9,045.62 5,635.81 5,954,776.54 564,417.90 0.00 9,045.62 BHL @ 16320' MD, 3947' ND: 359' FSL, 1992' FEL - Sec24-T11 N-R10E - 41l2" -1J-120 MB_A2 Toe (03/21/07) ~ '~ h~~~ =_ "~~~ _ .i °~,~ _ y~~~ ~ ~ ~ !~ ~ ~~ ~ ~ ~~ = ~a ~ ~ ~~ , P lan 1J 120< ~ ~~ ~~~ : ~~~ ~ _~_ ~ , ~ ~ _-° .~ ~ ~~~ ~ ~ ~ ,~ ~J~ _ °- , .~,,~ - ~ ', ~~~ ~i~~ ~ ~__. ~ ~~ __ - -- ~.. ~ ', ~ y ~ - ~~ _ ~ _ ~ I ~ - ~ ~~ ~ ~' ~~ ~~°~~~ _ = ~~+ ~ - ~~II ~ ~~ ' _ _ __ ~-~ ,' ~ ;i ~ - ~a~r~f~{ ~I ~ - ~ ~ ~~ ~ ~ ~--~~ ~ = ~ ~o k I i_ -- . Ii4~`' __ _ - _, I Ii~r~~i. -. . ., I~IF~~.~.~». , ~ ~ y i, ... _- , i~ef _.. m.wln ~~.. . _ __ - k' __m ~- 3,937.70 1J-120 MB_A2_CP3 (03l21/07) 4,142.88 5,729.55 5,949,875.15 564,549.95 - Polygon Point 1 0.00 0.00 5,949,875.15 564,549.95 Point 2 1,998.66 -46.27 5,951,873.11 564,488.07 3,948.20 1J-120 MB_A2_CP4 (03/21/07) 6,141.45 5,683.29 5,951,873.11 564,488.07 - Point 3,940.60 1J-120 MB_A2_CP7 (03/21/07) 7,640.87 5,648.91 5,953,372.07 564,441.98 - Polygon Point 1 0.00 0.00 5,953,372.07 564,441.98 Point 2 697.79 -16.24 5,954,069.56 564,420.29 3,947.10 1J-120 MB_A2_Toe (03/21/07) 9,045.62 5,635.81 5,954,776.54 564,417.90 - Point 3,626.22 1J-120 Top D(wp09) 1,094.16 5,782.00 5,946,827.23 564,626.22 - Point 3,947.10 1J-120 MB_A2_CP8 (03/21/07) 8,338.57 5,632.67 5,954,069.56 564,420.29 - Polygon Point 1 0.00 0.00 5,954,069.56 564,420.29 Point 2 707.30 3.13 5,954,776.54 564,417.90 3,720.00 1J-720 Top B(wp09) 1,583.72 5,788.32 5,947,316.78 564,628.71 - Point 3,937.30 1J-120 MB_A2_CP6 (03/21/07) 7,041.21 5,662.63 5,952,772.59 564,460.38 - Polygon Point 1 0.00 0.00 5,952,772.59 564,460.38 Point 2 599.88 -13.72 5,953,372.07 564,441.98 3/22/2007 11:18:06AM Page 9 of 10 COMPASS 2003.11 Build 48 A '~„'., ~ ~~ 6 ~" ~ ~ ~ ~ ~.~ ~ x ,~ . ~;~r ~~~~''~~ps Halliburton Company HAE.~,,,t~U~C1"~~V ~~ Compass Proposal Report - Geographic gP~,r~.y p~.~~ring Serviaes ~ • --- ~ ~ . _ - __ ,~_- ,~-~~~"_ - _ . -- ~ w. _-_ . ~ - ,-~ „~~'~, , Jb~ ~ k `~k . . ~ 0 .. .i~- ;,,-a~u~h~', ~ _ . i~ (~ II' -" ~ = ~~j~ `~ " ~ ~ty - ~~~a= i i i~ ~~ I '~I~I~~Vry ~~~ f~": S~) ii '~ ~' ~C W~l; ~ E~~ ( ~; .1~~ 'S, I~~~,~J 7 .. ,~"'. r<~ ~ $ ;~ts.~ ~ ii ~. ~i~~~ ._ a~ ~i ~ ~i~i i~ i ~i~ii~ "~p~ i~ ~~k ~i i~ ii ~ S ~~ .. ~ ; ( iiiii ~~ii~~ ~ ~ rr i _ i t~~t~~ ~ i t i i. i ~ ~ ~ ~~ , i~~~~~i i ~ ~.~ ~?. ~ ~. ~ ~ ~ a ~ ~~ ~ ~ ~ ' ~i i i i ~ i i ~ . n ~d~ ..~"~ ~ i .. .. . t - i ..... ~~~e~ . . 1,654.70 48.94 99.86 1,506.58 -76.63 510.45 Ptrost 1,897.55 56.59 99.86 1,658.11 -109.07 697.12 T3 2,727.69 69.00 99.86 1,979.92 -239.83 1,449.43 K15 3,470.05 69.00 99.86 2,245.96 -358.50 2,132.25 Casing Pt 5,879.06 73.89 77.70 2,988.89 -621.07 4,394.09 Ugnu C 7,058.39 74.96 40.44 3,305.52 -47.13 5,351.31 Ugnu B 7,355.86 75.24 31.05 3,382.02 185.93 5,519.05 Ugnu A 7,734.15 75.58 19.10 3,477.34 516.93 5,673.88 K 13 8,349.31 76.12 6.03 3,627.97 1,101.71 5,782.54 W SaK D 8,609.58 80.10 359.17 3,681.66 1,355.92 5,793.96 W Sak C 8,859.04 80.52 358.67 3,723.03 1,601.86 5,787.89 W Sak B 9,115.99 80.52 358.67 3,765.33 1,855.22 5,782.02 W SakA4 9,477.95 80.52 358.67 3,824.92 2,212.16 5,773.75 W Sak A3 11,218.79 88.84 358.67 3,933.71 3,945.88 5,734.13 W SakA2 28.01 28.01 0.00 0.00 SHL: 1875' FSL, 2357' FEL- Sec35-T11N-R10E 4,100.00 2,471.71 -459.20 2,711.67 10 3/4" Surface Csg. @ 4100' MD, 2472' TVD: 1416' FSL, 354'FWL - Sec36-l 8,137.30 3,576.50 897.31 5,759.79 Begin Pump Tangent @ 8137' MD, 3577' ND 8,337.30 3,625.07 1,090.12 5,781.28 End Pump Tangent @ 8337' MD, 3625' ND 10,092.14 3,909.91 2,819.78 5,759.90 7 5/8" Int. Csg @ 10092' MD, 3920' ND: 587' FNL, 1874' FEL - Sec36-T11 N- 16,320.22 3,947.10 9,045.61 5,635.81 BHL @ 16320' MD, 3947' ND: 359' FSL, 1992' FEL - Sec24-T11N-R10E 3/22/2007 11:18:06AM Page 10 of 10 COMPASS 2003.11 Build 48 ~ ~ ~ ~~ ~~~~. "/` Halliburton Company HAL.I~..IE3U~TiDN ~~Q~,~~~p~' Compass Proposal Report - Geographic q~~ ~~y Orl~ltng 8arviaes ~ '` • • Cano~oPh ~ I I i ps Afaska ~ Plan: 1J-120 (wp09) Sperry Drilling Services Anticollision Summary 23 March, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-120 Plan 1J-120 Local Coordinate Origin: Centered on Well Plan 1J-120 - Slot 1J-120 Viewing Datum: oyon 141 Plan RKB @ 109.OOft (Doyon 141 (28+81)) NDs to System: N North Reference: True Unit System: API - US Survey Feet ~~~~~~~~~~~ Sp.rry Ori[i[ng 8ervicss ~ ~ ~ ~~~, ~ ~~ ~ ,~~ ~. _ . , ;. ~ . • • SURVEY PROGRAM ConocoPhillips Alaska, Inc. AN71-COLLISION SETTINGS Date: 2007-03-317YIO:U0:110 Validatcd: Ycs Vcrsi nn: Engineering IMerpolation Method: MD Interval: 50S[a[ions Depth FromDepth Tu Sun~crlPlan T~rol Calculation Method: Minimum Curvature Error System: ISCWSA Depth Range From: 28.00 To 16320.23 Maximum Range:182922270881458 28.U0 lUUll.no 1b12n (x~~9) C6GYR0-SS Scan Method: Trav. Cylinder North Reference: Plan: 1J-120 (wp09) IOUII.nO 11N192.00 1J-120 (w~~N19) MN'D+IFR-.4K-CAZSC ErrorSuRace: Elliptical Conic IUUY2.001G320.27 1J-120 (..pIN) MN'D+~FR-.4K-C AZSC Warning Method: Rules BaSeA iJ-03 7J-118 7J-ir9 ~J-115 - ~ ~ ~ ~- - ~ {y ~~, ~._ ~ 330,„~ ~~ 7 ~L. 30 ,~9 '~~ '~ ~ i~ A 0 '~•~ ~~~ a' ~ y ~ ~~ ~ ~ A ~ ~ iJ 12 PiIM ( p03~ ~ y~~'~i~~ ' j~~~ t „ t. ~ WSP-OS 330 - 30 . - ~ . , 1Xd , 1J 164 1J-760 ~. W+ 1 -~,qry,~ I'~ ` ~ 1 -- ' ,,:r . ` ~a,o' 3~ ~.-~~.,~b ~~z ,~:, ~- ao ~, l ~ ~~~ ar~ " ~ -" r~- l'!SP-05 _ ~.~" ~ Fg' \ ~i ~`C~ ~ u 50 . ~ : . ~ 300 1Jd07(wp03) ° - ( ~ v y" 60 .'~ ~/ ~1+`ti , , I .._'7-- 7J-762~wp05) ~ /t ' '- ~~' ~ - ~~ .I ,~ ~ ~ ~,~ ~ i6?" ~ ~ \ , - ~ _ • WSP-05 -~ r r ~.~f ~ ~ ~ r~ ~ r .{ ~ ~___ ~/~~ . 5 ~ ~h~ ~ . `~: '~ ` \ ~ ~ ~ ~, ~ A % . ~ ~i l ~ _~,_ r ,P-c,~ ~ ,F ~~ _ ~ f ~ . .~p \ 1 . From Colour To MD 2~a '- -- so ' ' 1J 166 ~~~ 1 ~x l: ` ~ _._ ya ~ 4 : ' ~ ~ 1 i `7 , S ~ ~ T ~F ~ ~ ~ ~ '~~ ~ 28 250 ~ ' ~ ~ ~1 l . ~ ~ ~ 250 SW _ . 2;~. : 7J-27 (wp01) ~ ~-s'-,'~'~S^ - ~ ~ f r f~` ~ 1~ ~~~ 1{ f 500 750 ~, ~~ . /' ' ~ ~ ~ ~ ~ ' .hSP 07 .' k ! . ~~v ~4 ~'h'+ ~ ~ ~1~ ~ ~ ~ I j~ ~ ~ ~ ,s / ~7 ~~r`~ 750 _-- 1000 h40 ~ t ~ i ~r*" ~i`f ~ '~!C ~ ~ 120 ~f ~ 1J-16B• ~ 7` . h ~ ` ~ Y/i , ~ ~ l ~ + r - ~ ' 0 ti~~ ~ f~ - - Ky~. 0 i. WSP OB ' ' \ \ \ . F/ - r j l t 1250 1500 , /n , ~ .. / ` l ` ~ ' 240~ _`~ iJ-VO ' rt•~,..~ l ii~YT , . . ~ -,n i t ~ ~ / ~1 1500 _ _ _ .. . 17$0 t ~ \ f~ ~ t . - ~ 1 ~ ~~ ~ ` ' • \ ~ T, ~ 1J-17S (wp06) '' ~~ . ~ : i . / - ~ ~ 1750 2000 ~ 270 J .'.. ~ 150 : i~M ~ / .. :~~ ~ z . q ~ . 1 ~~~ ~ / 2000 2250 iJ-~3? t C?1 ~ 5~ ~ ~~ WSP-09~' ~ x- y .~ ~~ ~ `~1 ~~ ~ ~ ~ ~ { ~' i ~ 2250 2500 ~180 ~ f j ~ ~~ ~ . J ~ l J l I 1' ~~ 2500 3000 .' ~ 1J474(wp05~ i ti ~ J y r J~ '1~f~1 ~ fYt I~J~ ~ 3000'- ~~-4000 TrecclliogCyliodcrNimuth(TFO+AZq~°~vsCcntmmCeotreScpar~rioe~50ftlio~ , 270 ~ ~ i ~ 1W ~ . ~~x~t !~~~~ ~ ~4 ~~. .._ . ~ ~ < ~ 4000 5000 WSP-10 ~ , . ~ . ...~ . 780 1 J-t 21 (::~~~n2} ~ ~~ iJ 107 03 5000 8000 8000 7000 ~s ~ ~ 1J-tU9a~v:pu2) - (wp ) 1J-130~wp02~ ~~-~331ntermediate _'_' 7000 - 8000 -_ ' 8000 9000 o~ T°~^ Travelling Cylinder Azimuth (TFO+AZI) ~°~ vs Centre to Centre Separation ~150 R/in~ 9000 70000 iD000 16500 1000 125 ~ r ~ ' ~` / ~ ~ ' ~~ ' _.._.. _._ __ __... ...._ .._ ___ ._ ...._ NAD 27 ASP Zone 4: WELL DETAILS: PWn 1J-120 Grou~W Level: 81.00 +N/S.EI-W Northinq Eestlrp Latittude Longitutle Slot 0.00 0.00 5945888.02 558853.50 70°75'd3.975N 149°31'2711W 1J.720 REFERENCEINFORMATION Co-ortlinate (N/E) Reference: Well Plan 7J-120 - Sbt 1J-120, True North Vertiwl (ND) Reference: Doyon 141 Plan RKB ~ 109.OOIt (Doyon 141 (28~81)) Section (V5) RMerence: Sbt - 1J-120(O.OON, O.OOE) Mwsured Depth Reference: Doyon 1d1 Plan RKB ~ 709.00(t (DOyon 147 (28.81~~ Calculation Method: Minimum Curvature w _ ~~rv~wn ~s~m a u cs.t~wn ~+~ _ ae~wawn u~m _ a~m~~an ~i~ _ cPem~,wn ,s, _ ra.~on~u~ ORIGlI~A~ ~ Halliburton Company ~ Anticollision Report Company: ' ConocoPhillips Alaska Inc. Date: 3/23/2007 Time: 15:49:44 i Page: 1 Fietd: Kuparuk River Unit RePerence Site: Kuparuk 1 J Pad ' Co-ordinate(NE) Reference: Well: Pl~n 1.I-120, 7CUe f~forth Referenca We1L• I P(art 1J-120 Verticat (TVD) Reference: D141 (28 + 81) 109.4 Reference Wellpath: i Plan 1 J-120 ' Db: ~r2cle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Plan: 1J-120 (wp09) & NOT PLANNED P Interpolation Method: MD + Stations Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 28.00 to 16320.20 ft Scan Method: Trav Cylinder North Maximum Radius; 1829.22 ft Error Surface: Ellipse + Casing Casing Points NID '~~} Diarneter Holc Size Name' ft ft 'I in in 3341.80 2200.00 10.750 13.570 10 3/4" 9380.53 3808.89 7.625 9.875 7 5/8" 15568.71 3946.68 4.500 6.750 41/2" Plan: 1 J-120 (wp09) Date Composed: 10/12/2006 Version : 4 PrincipaL• Yes Tied-to: From Well Ref. Point Summary <= -----------------~ Offset Welipath --________:_____a Referenc~ Offset ' Ctr-Ctr NaGo' A~llowable ' Site I Well Wellpath MD ! MD Distance Area i Deviation Waruing ! ft ' ft ft ft ft: Kuparuk 1 D Pad 1 D-138 1 D-138 VO Out of range Kuparuk 1 D Pad 1 D-141 1 D-141 VO Out of range Kuparuk 1 D Pad 1 D-141 1 D-141 L1 VO Out of range Kuparuk 1 D Pad 1 D-30 1 D-30 V6 Out of range Kuparuk 1 D Pad 1 D-30 1 D-30L1 V2 Out of range Kuparuk 1 D Pad 1 D-32 1 D-32 V5 Out of range Kuparuk 1 D Pad 1 D-32 1 D-32L1 V1 Out of range Kuparuk 1 D Pad 1 D-32 1 D-32L1 PB1 V1 Out of range Kuparuk 1 D Pad 1 D-34 1 D-34 V6 16308.73 8175.00 629.20 266.87 362.34 Pass: Major Risk Kuparuk 1 D Pad 1 D-36 1 D-36 V4 16319.54 7950.00 1661.67 232.05 1429.62 Pass: Major Risk Kuparuk 1 D Pad 1 D-36 1 D-36L1 V3 16320.15 7950.00 1661.61 230.53 1431.08 Pass: Major Risk Kuparuk 1D Pad 1D-36 1D-36L2 V1 16320.15 7950.00 1661.61 230.53 1431.08 Pass: Major Risk Kuparuk 1 D Pad 1 D-37 1 D-37 V4 Out of range Kuparuk 1 D Pad 1 D-37 1 D-37L1 V1 Out of range Kuparuk 1 D Pad 1 D-37 1 D-37L2 V3 Out of range Kuparuk 1 D Pad 1 D-37 1 D-37L2P61 V1 Out of range Kuparuk 1 D Pad 1 D-39 1 D-39 V2 16320.42 8525.00 1301.32 204.19 1097.13 Pass: Major Risk Kuparuk 1J Pad 1J-03 1J-03 V9 291.39 300.00 241.51 5.27 236.24 Pass: Major Risk Kuparuk 1J Pad 1J-10 1J-10 V7 291.33 300.00 217.22 5.21 212.02 Pass: Major Risk Kuparuk 1J Pad 1J-109 1J-109 V1 261.73 275.00 221.06 5.66 215.40 Pass: Major Risk Kuparuk 1J Pad 1J-109 1J-109P61 V3 261.73 275.00 221.06 5.77 215.29 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115 V2 323.96 325.00 100.44 5.41 95.03 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115L1 V1 323.96 325.00 100.44 5.28 95.16 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115L1P61 V1 323.96 325.00 100.44 5.41 95.03 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115L1PB2 V1 323.96 325.00 100.44 5.41 95.03 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115L2 V2 323.96 325.00 100.44 5.28 95.16 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115L2P61 V4 323.96 325.00 100.44 5.41 95.03 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115L2P62 V3 323.96 325.00 100.44 5.41 95.03 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115P61 V1 323.96 325.00 100.44 5.41 95.03 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115P62 V1 323.96 325.00 100.44 5.41 95.03 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115P63 V1 323.96 325.00 100.44 5.41 95.03 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115PB4 V1 323.96 325.00 100.44 5.41 95.03 Pass: Major Risk Kuparuk 1J Pad 1J-127 1J-127 V6 912.19 925.00 119.80 17.63 102.17 Pass: Major Risk Kuparuk 1J Pad 1J-127 1J-127L1 V2 912.19 925.00 119.80 17.50 102.30 Pass: Major Risk Kuparuk 1J Pad 1J-127 1J-127L1P61 V2 912.19 925.00 119.80 17.63 102.17 Pass: Major Risk Kuparuk 1J Pad 1J-127 1J-127L2 V1 912.19 925.00 119.80 17.50 102.30 Pass: Major Risk Kuparuk 1J Pad 1J-127 1J-127PB1 V1 912.19 925.00 119.80 17.63 102.17 Pass: Major Risk Kuparuk 1J Pad 1J-127 1J-127P62 V1 912.19 925.00 119.80 17.63 102.17 Pass: Major Risk Kuparuk 1J Pad 1J-'i33 1J-133 V2 301.88 300.00 259.22 5.73 253.49 Pass: Major Risk Kuparuk 1J Pad 1J-164 1J-164 V3 273.33 275.00 166.19 5.33 160.87 Pass: Major Risk Kuparuk 1J Pad 1J-164 1J-164L1 V1 273.33 275.00 166.19 5.20 161.00 Pass: Major Risk Kuparuk 1J Pad 1J-164 1J-164L2 V2 273.33 275.00 166.19 5.33 160.87 Pass: Major Risk Kuparuk 1J Pad 1J-164 1J-164L2P61 V1 273.33 275.00 166.19 5.33 160.87 Pass: Major Risk Kuparuk 1J Pad 1J-166 1J-166 V5 273.46 275.00 150.62 5.09 145.52 Pass: Major Risk Kuparuk 1J Pad 1J-166 1J-166L1 V3 273.46 275.00 150.62 4.96 145.66 Pass: Major Risk Kuparuk 1J Pad 1J-166 1J-166L1P61 V3 273.46 275.00 150.62 4.96 145.66 Pass: Major Risk )GRAM ~~~-;~~,~~x ~ ;~; ' ~ e ~ a ~ ~ . r~ ~~ ~.». ! Halliburton Company ~ Anticollision Report Company: i ConocoPhiliips Alaska Inc. Date: 3/23/2007 Time: 15:49:44 Page: ! 2 Fietd: Kuparuk River Unit Reference Site: ' Kuparuk 1J Pad ' Co-ordinate(NE) Reference: Well: Plan 1,1-'~20, True North Reference Vi'e1L Plan 1J-120 Verticat (TVD) Reference: D141 (2$ + 81)109.0 Reference Wellpath: i Plan 1J-120 Db: Oracle Summary <'~_~________________ Offset Wellpath --- ----------------> ' Reference 'Offset ' Ctr-CtX No-Go : AllowabKe Site ' Well WellpatL MD MD ! Distance Are~ Deviatio~ Warning : ift ft ft ' ft ' ft Kuparuk 1J Pad 1J-166 1J-166L2 V1 273.46 275.00 150.62 5.09 145.53 Pass: Major Risk Kuparuk 1J Pad 1J-166 1J-166L2P61 V1 273.46 275.00 150.62 5.09 145.53 Pass: Major Risk Kuparuk 1J Pad 1J-168 1J-168 V5 250.00 250.00 147.03 4.91 142.11 Pass: Major Risk Kuparuk 1J Pad 1J-168 1J-168L1 V3 250.00 250.00 147.03 4.78 142.24 Pass: Major Risk Kuparuk 1J Pad 1J-168 1J-168L2 V2 250.00 250.00 147.03 4.78 142.24 Pass: Major Risk Kuparuk 1J Pad 1J-168 1J-168L2PB1 V1 250.00 250.00 147.03 4.91 142.11 Pass: Major Risk Kuparuk 1J Pad 1J-170 1J-170 V2 273.69 275.00 150.63 5.42 145.21 Pass: Major Risk Kuparuk 1J Pad 1J-170 1J-170L1 V1 273.69 275.00 150.63 5.29 145.34 Pass: Major Risk Kuparuk 1J Pad 1J-170 1J-170L2 V1 273.69 275.00 150.63 5.29 145.34 Pass: Major Risk Kuparuk 1J Pad 1J-170 1J-170PB1 V1 273.69 275.00 150.63 5.42 145.21 Pass: Major Risk Kuparuk 1J Pad 1J-170 1J-170PB2 V1 273.69 275.00 150.63 5.42 145.21 Pass: Major Risk Kuparuk 1J Pad Plan 1J-107 Plan 1J-107 L1 VO Plan 7420.19 7550.00 153.33 102.81 50.51 Pass: Major Risk Kuparuk 1J Pad Plan 1J-107 Plan 1J-107 L2 V0 Plan 7420.19 7550.00 153.33 102.81 50.51 Pass: Major Risk Kuparuk 1J Pad Plan 1J-107 Plan 1J-107 V1 Plan: 1 7420.19 7550.00 153.33 102.92 50.41 Pass: Major Risk Kuparuk 1J Pad Plan 1J-111 Plan 1J-111 V1 Plan: 1 371.89 375.00 181.02 7.66 173.36 Pass: Major Risk Kuparuk 1J Pad Plan 1J-112 Kuparuk Plan 1J-112 W Lat V0 P 359.48 375.00 160.94 6.73 154.20 Pass: Major Risk Kuparuk 1J Pad Plan 1J-119 (M15 P h~lan 1J-119 VO Out of range Kuparuk 1J Pad Plan 1J-120 Plan 1J-120 L1 VO Plan 50.00 50.00 0.04 0.00 0.04 Pass: No Errors Kuparuk 1J Pad Plan 1J-120 Plan 1J-120 L2 VO Plan 5175.00 5175.00 0.00 0.00 0.00 FAIL: No Errors Kuparuk 1J Pad Plan 1J-122 Plan 1J-122 V2 Plan: 1 564.83 575.00 43.45 10.64 32.81 Pass: Major Risk Kuparuk 1J Pad Plan 1J-123 Plan 1J-123 Kuparuk Pr 613.00 625.00 57.67 12.63 45.05 Pass: Major Risk Kuparuk 1J Pad Plan 1J-124 Plan 1J-124 V2 Plan: 1 465.43 475.00 82.11 8.71 73.41 Pass: Major Risk Kuparuk 1J Pad Plan 1J-129 Plan 1J-129 V2 Plan: 1 1899.69 1850.00 163.63 40.38 123.25 Pass: Major Risk Kuparuk 1J Pad Plan 1J-130 Plan 1J-130 V2 Plan: 1 883.98 875.00 202.97 17.34 185.63 Pass: Major Risk Kuparuk 1J Pad Plan 1J-132 1J-132 V2 Plan: 1J-132 521.73 525.00 241.17 9.52 231.65 Pass: Major Risk Kuparuk 1J Pad Plan 1J-160 Plan 1J-160 L1 V4 Plan 285.01 300.00 231.92 6.18 225.74 Pass: Major Risk Kuparuk 1J Pad Plan 1J-160 Plan 1J-160 L2 VO Plan 285.01 300.00 231.92 6.18 225.74 Pass: Major Risk Kuparuk 1J Pad Plan 1J-160 Plan 1J-160 V1 Plan: 1 285.01 300.00 231.92 6.23 225.69 Pass: Major Risk Kuparuk 1J Pad Plan 1J-160 Rig 1J-160 V1 209.40 225.00 232.37 4.46 227.91 Pass: Major Risk Kuparuk 1J Pad Plan 1J-162 Plan 1J-162 L1 V2 Plan 273.21 275.00 189.23 5.62 183.61 Pass: Major Risk Kuparuk 1J Pad Plan 1J-162 Plan 1J-162 L2 VO Plan 273.21 275.00 189.23 5.62 183.61 Pass: Major Risk Kuparuk 1J Pad Plan 1J-162 Plan 1J-162 V5 Plan: 1 273.21 275.00 189.23 5.85 183.38 Pass: Major Risk Kuparuk 1J Pad Plan 1J-173 1J-73 Kuparuk Producer 310.19 325.00 176.98 5.94 171.04 Pass: Major Risk Kuparuk 1J Pad Plan 1J-174 Plan: 1J-174 V1 Plan: 274.91 275.00 189.18 5.87 183.31 Pass: Major Risk Kuparuk 1J Pad Plan 1J-174 Plan: 1J-174L1 VO Plan 274.91 275.00 189.18 5.98 183.20 Pass: Major Risk Kuparuk 1J Pad Plan 1J-176 Plan: 1J-176 L1 VO Pla 274.08 275.00 216.80 5.03 211.78 Pass: Major Risk Kuparuk 1J Pad Plan 1J-176 Plan: 1J-176 VO Plan: 274.08 275.00 216.80 5.03 211.78 Pass: Major Risk Kuparuk 1J Pad Plan 1J-L14(BQ) Plan 1J-L14(BQ) VO Pla 7079.25 6625.00 380.33 100.92 279.42 Pass: Major Risk Kuparuk 1J Pad Plan 1J-L15(BP) Plan 1J-L15 D Lateral 1110.51 1025.00 426.55 20.37 406.18 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-105 1J-105 L1 V1 Plan: 1J- 297.87 300.00 320.31 6.42 313.89 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-105 1J-105 L2 VO Plan: 1J- 297.87 300.00 320.31 6.27 314.04 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-105 1J-105 V2 Plan: 1J-105 297.87 300.00 320.31 6.42 313.89 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-118 Plan: 1J-118 L1 V3 Pla 374.24 375.00 41.02 7.44 33.58 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-118 Plan: 1J-118 L2 V1 Pla 374.24 375.00 41.02 7.44 33.58 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-118 Plan: 1J-118 V4 Plan: 374.24 375.00 41.02 7.59 33.43 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-118 Rig: 1J-118 V0 374.22 375.00 38.89 6.99 31.90 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-118 Rig: 1J-118PB1 VO 374.22 375.00 38.89 6.99 31.90 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-118 Rig: 1J-118PB2 V0 374.22 375.00 38.89 6.99 31.90 Pass: Major Risk Kuparuk 1J Pad WSP-02 WSP-02 V4 463.55 475.00 202.66 7.28 195.38 Pass: Major Risk Kuparuk 1J Pad WSP-03 WSP-03 V1 550.80 550.00 145.53 14.23 131.30 Pass: Major Risk Kuparuk 1J Pad WSP-04 WSP-04 V1 540.85 550.00 85.86 8.87 76.99 Pass: Major Risk Kuparuk 1J Pad WSP-05 WSP-05 V1 637.75 650.00 28.21 15.86 12.35 Pass: Major Risk Kuparuk 1 J Pad WSP-06 WSP-06 V1 764.96 775.00 29.28 19.41 9.87 Pass: Major Risk Kuparuk 1J Pad WSP-07 WSP-07 V1 840.71 850.00 84.64 25.25 59.39 Pass: Major Risk Kuparuk 1J Pad WSP-08 WSP-08 V2 932.20 925.00 138.01 28.97 109.04 Pass: Major Risk Kuparuk 1J Pad WSP-09 WSP-09 V1 973.58 975.00 194.34 23.74 170.60 Pass: Major Risk Kuparuk 1J Pad WSP-10 WSP-10 V1 1019.88 1000.00 242.52 24.82 217.70 Pass: Major Risk Kuparuk 1J Pad WSP-11 WSP-11 V1 1150.16 1150.00 307.05 26.16 280.89 Pass: Major Risk Kuparuk 1J Pad WSP-20 WSP-20 V1 299.62 300.00 203.04 6.29 196.76 Pass: Major Risk ~~0~°°lR~:~ ; --~ ° ' „ ~ ~ 3 , ~s ' Schlumberger CemCADE Prelimina'ry Jo~ L~~esigr~ ~ t~ 3f4'~ Sur~ac~ ~ ~ ~ ~ ,, ; Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 141 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 2/7/2007 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@slb.com < TOC at Surface Previous Csg. < 20", 91.5# casing at 80' MD < Base of Permafrost at 1,653' MD (1,505' ND) ~ Top of Tail at 3,027' MD < 10 3/4", 45.5# casing in 13 1/2" OH TD at 3,828' MD (2,260' ND) ~ Mark of Schlumberger Volume Calculations and Cement Svstems Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. The top of the tail slurry is designed to be at 3,027' MD. (800' above the shoe) Lead Slurrv Minimum pump time: 280 min. (pump time plus 120 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 1.3644 ft3/ft x(80') x 1.00 (no excess) = 109.2 ft3 0.3637 ft3/ft x(1653' - 80') x 3.50 (250% excess) = 2002.4 ft3 0.3637 ft3/ft x(3027' - 1653') x 1.35 (35% excess) = 674.6 ft3 109.2 ft3 + 2002.4 ft3+ 674.6 ft3 = 2786.2 ft3 2786.2 ft3 / 4.45 ft3/sk = 626.1 sks Round up to 630 sks Have 290 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurrv Minimum pump time: 210 min. (pump time plus 120 min.) DeepCRETE @ 12.0 ppg - 2.47 ft3/sk 0.3637 ft3/ft x(3828' - 3027') x 1.35 (35% excess) = 393.3 ft3 0.5400 ft3/ft x 80' (Shoe Joint) = 43.2 ft3 393.3 ft3 + 43.2 ft3 = 436.5 ft3 436.5 ft3/ 2.47 ft3/sk = 176.7 sks Round up to 180 sks BHST = 50~, Estimated BHCT = 65~. (BHST calculated using a gradient of 2.6`F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time ~bpm~ (bbl) ~min) (min) CW 100 5 50 10.0 10.0 Drop Bottom Plug 15.0 25.0 MudPUSH II 5 50 10.0 35.0 Lead Slurry 7 499 71.3 106.3 Tail Slurry 6 79 13.2 119.5 Drop Top Plug 8.0 127.5 Water 6 20 3.3 130.8 Switch to Rig Pum s 5.0 135.8 Displacement 6 320 53.3 189.1 Slow Rate 3 20 6.7 195.8 MUD REMOVAL Recommended Mud Properties: 9.6 ppg, P~ < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, P~ = 17-21, TY = 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. ~ ~"` ~ ~ ~~. ~ ~~ ~ t, S 4 ~ ~~~ t~K ~.. ' Schlumberger - CemCApE Prelimir~ary Joki aesign 7.625" Inf~rrnediaf~ Casir~ '", = Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Svstems Volumes are based on 25% excess. Tail slurry is designed for 500' MD above the Ugnu C(6265' - 500' = 5765' TOC, 4200.7' MD annular length). Tail Slurrv Minimum thickening time: min. (Pump time plus 120 min.) DeepCRETE @ 12.5 ppg - 2.25 ft3/ft 0.2148 ft3/ft x 4200.7' x 1.25 (25% excess) = 1127.9 ft3 0.2578 ft3/ft x 80' (Shoe Joint) = 20.6 ft3 1127.9 ft3 + 20.6 ft3 = 1148.5 ft3 1148.5 ft3/ 2.25 ft3/sk = 510.4 sks Round up to 520 sks BHST = 92`F, Estimated BHCT = 59~. (BHST calculated using a gradient of 2.6~/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage b m Volume Time ~ p ) (bbll (min) Iminl CW 100 5 50 10.0 ----, 10.0 Drop Bottom Plug 10.0 20.0 MudPUSH II 5 75 15.0 35.0 Tail Slurry 5 208 41.6 76.6 Drop Top Plug 10.0 86.6 Water 5 20 4.0 90.6 Switch to Rig Pumps 5.0 95.6 Displacement 6 384 64.0 159.6 Slow Rate 3 50 16.7 176.3 MUD REMOVAL Recommended Mud Properties: 8.9 ppg, P~ < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 11.0 ppg MudPUSH* II, P~ = 19-22, TY = 22_2g Centralizers: Recommend 1 perjoint across zones of interest and 2 per joint over the last two joints to ensure proper placement. ~~~~~~~~W~~ ~ ~ ~ ! ~ i S 'Insulated conductor, 20" 94# K55 x 34" 0.312", set at +/- gp~ MD. 'Wellhead / Tubing Head / Tree, 10-3/4" x 4-112", 5,000 psi. ~ Tubing String ConocoPhillips 47/7' 12.6#, L-80, IBTM ~.sss° io, 3.833~~ Drift West Sak 7-5/8" Producer ~ ` GLM, Camco 4-1/2" X 1" KBMG 1 J~~~ O ~\, c~M,Camco4-1/r~X,~~KBMG Tri-Lateral Completion \ wp_09 103/4" 45.5# L-80, Bot[om of Motor Centralizer Casing Shoe, set (~ Centralift 418 HP KMHFER 2610 / 98 with FC6000 pump 4100' MD, 2,472' ND~; \ D-sand Window '\ 8347' MD, 3626' ND \ 'D' Sand Lateral ECP 4-~12" 11.6# LBO Slotted Liner Every Joint 4-112" Guide Shoe 4-112" X 7518•• Model'B' HOOK Fla Assemblv 5-112" X 7518" ZXP Lmer Top Packer with Hold Downs ~~ Casing Sealbore Receptacle 4.75" ID Orienting Profile I~~ Automatic Alignment of LEM Positive Latching Collet ~- Indicates Correct Location ~ Seal Bore forlateral ~ Isolation - 3.68" ID Access Window ` Positive Lateral Access Via \ Thru-Tubing Diverter \ Seal Bore for Lateral Isolation - 3.68" ID ~ Isolatlon Seal Asembly 4.75" Seal OD 3.875" Seal ID 4-112" X 4-112" 12.6# ID 5-112" 75/8" ZXP ~ LinerT Packer ~ with Hol owns 5- 2" X 7S18" Liner Hanger 1 Packer Assembly at x Lock +1-8950 MD Line anger Casing Sealbore ceptacli . "ID ~5-%" Tieback Sleeve Bent Muleshoe DB Nipple BAKER ~ FINGIlS Baker Oil Tools As Planned Late With ral Entry Module (LEM~ Di rt d I l ti ve ers an so a on Lateral Access DiveAer Lateral Isolation Diverter GS Running Tool String i~sWlled installed (3.00" Latenl DriR) (2.50" 10 Mainbor e ~rik) 'CaS' Profile fof Coil Connector JRunning/Retrieving \ (1.00' LengthJ Snap INSnap Out ~PositiveLOCating~ - rBackPressureValve ' Collet (7.60 Length) Lateral Isolation ~' ~ Flow-Thru Swivel Seals ~125' Lengfh) J~terel Diverter ~ II ~~Nydraulic Ramp I Disconnect ' ' IsolatioN Mainbore~ (1.50 Lenglh) DiverterSleeve I / GS Spear ~ ~ (1.50' Length) Lrteral Isolation~ 6.85 R Approx. Seals OAL' 'Jars may be required in highly tleviatetl 18.5' Diverter Length 7g.5' Sleeve Length ' or deep applications (6 approa length). Guide Shoe 4-112" Liner Shoe, 11.6it, L-80 BTC Set @ 16057' MD, 3803' ND 1 a-~~ ~; --~_. _ Seal Assembly 4.75" Seal OD - 3.875"ID ~A' Sand Undulating Lateral ~ 4-112" 11.6# L-00 Slotted Liner Every Joint wl ¢~~y• Eccentric ~ constrictorsforisoWtion ,Guitle Shoe Equioment Specifications 4-1/2" X 7-5/8" HOOK Hanger Mainbore Drift: 5.32" Mainbore Drik, with diveRer: 4.63" Lateral Drift, no diverOer or LEM: 3.88" Lateral Drift, wl diverter, no LEM: 3.88" LaterallMainbore Diverter OD: 6.75" 4-1/2" Lateral Entry Module Mainbore Dri(t: 3.65" Mainbore Drik, wl isolation sleeve: 2.50" Lateral Drift, wl coil diverter: 3.00" ~\ OD of Diverter and Sleeve: +I- 3.69" Diverter and Skeve Length: +1-18.5' 4-1/7' Casing Shoe, 11.~# L-80 BTC Set @ 16320' MD, 39fFT ND , asing Shce, Set ~ eaw« H~Bne: xoos. rni: ao~~~~~ ~y~o~ oe rev~oa~oea or ai:mn~aa, i~ „mae o. m P,n, i~,~yrorm or ey at @ 1009T MD, 3910' ND, 88 deg inc ~y ~so:.karw,io or mecn~~iwi, ma~ame v~oro~onme, reoomi~9, or ey a~y mrwr~wuo~ :wr:ae aoa reo-~..i sr:o~m ~ow ~ow~ or nere,rter i~~Mma, Vnmo~~ wr+a~ n~::~o~ rtom eax:r H~ene: i~o. /~\ ~- 4-1/2" Liner Shoe, 11.6#, L-80 BTC / 5-%" Tieback Sleeve Set @ 76050' MD, 3737' ND ':" Bent Muleshce naer Lateral Entry Module~LEM) 5-~12" X 751 P Orienting Profile LinerTopPacke ith Hold Downs B-sand Window (LEMI at 8841' MD, 3720' ND ca5~ Sealbore 'B' Sand Lateral Rece cle 4.75" payzone ECP 4-t12" 11.6# L-80 Slotted A, . Liner Every Joint ~ i t,.~ ...c~.B 4. .. ~:...~:'F .. ak ~~-~} ,. .nr~. ..= ~:~_~~ ,_~: ~ Conc~c Phillip-s ~~~ ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan: 1J-120 (wp09) 1/4 Mile Pool Scan Sperry Drilling Services March 22, 2007 ,~ ~ ..~ ~ ~ HALLIBURTON Drilling and Forrnatiion Evaluation ~~ ~ ~ Closest in POOL .~~~.., ,~~";:. ~_,, ~ ~ ~ Closes t A roach: Reference Well: 1J-12 0 w 09 Plan Offset Well: 1 D-141 L1 Coords. - Coords. - ASP ASP 3•D ctr-ctr [-I=.:;~riz~ ~ ` ,, asd=a Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist } ~t°+ ^a ~ e: Depth Inci. An le TRUE Azi. TVD E+~W - (0° Comments De th Incl. An le TRUE Azi. TVD E+/W - 0° Comments in istance POOL Min Distance (326.26 ft) in POOL (326.26 ft) in POOL (8260.8 - 16320.23 (8260.8 - 16320.23 MD) to 1J-120 (wp09) MD) to 1D-141L1 Plan (5890 - 9480 326.26 ~ -2~?~ ?d ,> 16320.23 90.09 0.51 3838.322 5954777.6 564418 9045.555 (5890 - 9480 MD) 9480 89.69 181.54 3633.074 59549392 564222.5 9206.808 MD) Closes t A roach: Reference Well: 1J-12 0 w 09 Plan Offset Well: 1 D -34 Coords. - Coords. - ASP ASP 3-D ctr ctr ;.zr, f~i t:~ fr°.,; ~ Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. i<i.,r ` z: Ee~ De th Incl. An le TRUE Azi. TVD E+)~W - 0°) Comments De th Incl. An le TRUE Azi. TVD E+/W - 0° Comments m istance POOL Min Distance (597.52 ft) in POO (597.52 ft) in POOL (8260.8 - 16320.2 (8260.8 - 16320.23 MD) to 1J-920 (wp MD) to 1 D-34 (7883 - Plan (7883 - 8767 597.52 '!! ~ "i's, >xlti G 16320.23 90.09 0.51 3838.322 5954777.6 564418 9045.555 8767 MD) 7960.92 68.42 155.66 3649.681 5954946.7 564959.1 9208.305 MD) Closest A roach: Reference Well: 1J-120 w 09 Plan Offset Well: 1J-118 L2 Coords. - Coords. - ASP ASP -D ctr-ctr h, ;~ ~ n- ~,ub~~: : Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS in. Dist. "~ t`'=:= _•r De th Incl. An le TRUE Azi. TVD E+/W - 0° Comments De th Incl. An le TRUE Azi. TVD E+/W - 0° Comments P L Min Distance POOL Min Distance (1213.74 ft) in POOL (1213.74 ft) in POOL (8260.8 - 16320.23 (8260.8 - 16320.23 MD) to 1J-120 (wp09) MD) to 1J-118 L2 Plan (7205 - 14822 1213.74 : ``6 8700 80.47 358.55 3587.88 5947178.5 564633.8 1445.005 (~205 - 14822 MD) 7181 79.43 357.9 3492.36 5947165.2 563423.9 1402.26 MD) losest A roach: Reference Well: 1J-120 w 09 Plan Offset Well: 1J-03 Coords. - Coords. - ASP ASP 3-D ctr ctr ~..; iz~ nt~.1 ° ui:.: a: Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. ';r~n~;~ r; r; s= De th Incl. An le TRUE Azi. ND E+~W - 0° Comments De th Ind. An le TRUE Azi. TVD E+~W - 0° Comments P L Min istance POOL Min Distance (1283.23 ft) in POOL (1283.23 ft) in POOL (8260.8 - 16320.23 (8260.8 - 16320.23 MD) to 1J-120 (wp MD) to 1 J-03 (6172 - Plan (6172 - 6990 1283.23 1:'ai t? ~'(}?_r4t's 9975 84.49 358.69 3793.467 5948436.1 564594.4 2702.876 6990 MD) 7014.87 66.21 60.2 3835.47 5948388.9 563312.8 2433.64 MD) Closest A roach: Reference Well: 1J-120 w 09 Plan Offset Well: 1J-105 w 05 Coords. - Coords. - ASP ASP 3-D ctr-ctr r( ;°izc~i~ta~ ~~ ii.:€ ::; Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Min. Dist. °i^st~n ua~~r~~ ~ De th Incl. An le TRUE Azi. TVD E+~W - 0° Camments De th Incl. An le TRUE Azi. TVD E+/W - 0° Comments POOL Min Distance POOL Min Distance (1699.16 ft) in POOL (1699.16 ft) in POOL (8260.8 - 1632023 (8260.8 - 16320.23 MD) to 1J-105 (wp05) MD) to 1J-120 (wp09) (7138.84 - 11769.93 Plan (7138.84 - 1699.16 '1~ 3~ 'I -' <! i' I<=,~ 8275 75.94 6.36 3501.117 5946763.4 564619.8 1030.011 MD) 7125 77.2 171.17 3493.62 5945960.7 5631222 239.14 11769.93 MD) POOL Summary Template.xis 3/22/2007 4:13 PM 0 0 ~ ~ ~ 0 0 0 v ~ a G)MOON N 0 N ~ lnrh7 ~ 0 _ H ~ M 00 fV ~ ~ N ~ Zc-1~ ~ y ~ n ~ Vl t~ Of N tD ~ ~ ~ M M ~ N M N J Q H W 0 ~ Z ~ Q U p~r~o ~r~rno ~~ f~ N M v ~c r N C9 M Q O N t O ~0000 O ~ T O ~ ~ ~ M O ~ODfO a-- O ~ N M Z ~ l6 N d J ~ N N Y ~ 3 7 7 Q C C m R Yaa Y ~ d N ~ ~ N ~ ~~ -a ._ ~~ O C u° c 0 T O 0 ~ O T ~ + ~ N a ~ m Y K N a ~oN O Ty ~ W G N N ym>X >Yaa ~~~¢ ~ oi o~ ~ c c o t ;~ ~ Zw Z ° °u ~ ~ F o ~ ~ m ~ J ~ J ~ 0 a~ = a N (u!M OOS£) (+141~oN/1-143~oS O O ~ O ~ O O O ... ~ c ~ O 0 b M t N O W O : ~ .... M y d ~ O O O ~ (`') O O O ti 0 0 ~ 0 ~ ORIGINAL ~ • ~ ~..J ~'~2ANSl~IT"~'AI, LET"~'Ela CH~CKLIS'I' `WEL,L ~ANtE /C~l~(,. ~d^ ~Z~ ~~~# ~ 7~0 yS' ~Devetopment Service Expioa-atory Stratigraphsc ~'est Yon-Conventioaal Well Circle 4ppropriate Letter / Paragraphs to be Included in Traasmitta! Letter , ~ CE{ECK ~ ADD-ONS ~ ; T'EXT FOR APPROVAL LETTER ; 46`HAT ~ (OPTIONS) i ' APPLIES ~ ' I ~ I I NtLiLTI LATERAL ~ The permit i~ for a new wellbore segment of existing ~ i ~ we(( ~ ~(If (a.st two digits in I Permit Vo. API No. ~0- - - i APi number , are ~ ', between 60-69) Production shou(d continue to be repoRed as a function of the ~ i -- ~ originai API number stated above. ~ ~ ~ PILOT HOLE ~ i[n accordance with 20 AAC 2~.00~(~, a!( records, data and lo~s ; ; ; acquired for the pilot hoie must be c(ear(y differentiated in both ~ i ; well name ( PF~ and API number ~ ; '(50- - -_) from records, data and lo~s ~ ' ~ acquired for well I ~ SPf1CING The permit is approved subject to full compliance with 20 AAC ~ ; EXCEPTION ~ 2~.0>j. Approval to perforate and produce / in1ect is continaent ; ; I upon issuance of a conservation order approving a spacing i i l exception. assumes the ~ ~ ~ i liability of any protest to the spacing exception that may occur. I a i DRY D[TCH ~ ~~-ll dry ditch samp(e sets subrnitted to the Commission must be in ; i SA!~iPLE I no greater than 30' sampte intecvals from be(ow the permafrost or ! ! ~ I from where samp(es are first caught and 10' sample intervals j ,' ~ through target zones. ; ' ; Please note the fo[lowing specia! condition of this permi±: ~ j Non-Conventional ~ ~ production or production testing of coal bed methane is not allowed i I~'j' z<< ~ for (name of wetl) until after (Companv Name) has desie ed and i ~ i ~ imp(emented a water well testing program to provide baseline data ~ ; on water quality and quantity. (Companv Name) must contact the i ! Commission to obtain advance approval of such water well testing ! ~ program. ~ Rev: 1:2~r'06 C 'jody~transmittal_checklist ~ ~ ^^ ~ y ~ , , ~ , ~ . ~ ~ ~ , ~ , ~ ~ ~ ~ ~ . ~ ~ ~ . , ~ ~ ~ . ~ , ~ ~ , ~ ~ , . pI O N ~ : , , ~ ~ . , . ~ ~ ~ ~ . . ~, ~ ~ ~ ~ . ~ ~ , ~ ~ , ~ ~ , ~ ~ . ~, . . ~ ~ ~ , ~ ~ ~ ~ . ~ ~ . , ~ ~ ~ ~ ~ i ~ ~ , . . ~ , . . ~ ~ ~ , ~ . ~ ~ , ~ , .. 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' , ~ , 'Q ° c~ ~ , ~ g N W, •°-~ c f6 ~ ~~ ~ ~n az 3~, ~ , , ,.o ~ , c.~'i ~ W ~ c Uj Q~ E Q fA ~ S i, C~ ~~ ~ ~ , 0~ O~ _~ ~~ ~ ~ ~ ~ , ~ ~ ~ , ~ ~ N ~ ~~ ~ ~ ~ ~ ~ ~ ~~ ~ y~ ~ p~ ~ C, ~ ~ , ~ q ~ Q ~ ~ ~~ N~ ~ ~ 3, N~ uj~ ~ _, ~~ ~, , ~ ~ ~ 7~ ~ ~ ~ ~ , ~ ~ ~ , N~ ~~ ~~ «~ ~ N ' ~ ~ ~ ~ ~~~ , , ~ ~ p~ N~ ~~ , ~ ~ ~ , ~ ~ ~ , ~ ~ , ~ ~ , ~ , ~ ~ ~~ ~ ~ . ~ , ~ ~ Z ~ ~~ , ~ ~~ , ~ ~ , ~ ~~ Y ° , ~ ~, ~~ , Q ] ~ ao o, a ~ , j ~ ~ ~ I-, ao r i r a o~, -~ N •3 , ~ ~I ( ~ ~ o~ , _ a ~, ~ ~~~ ,~~ ~ ~' m ~ ~ , ~ ~ , ~ 1 ~~ ~ V ~ ~ c ~' ~ ~ o , "a, °' ~ ~~~ . ~ 'u~~ ~~ ~ ~, E~ ~ <° ~ ~n Y L , , m ~ ~ ~ ~ ~ ~ ~. ~ C a~' rn C N ~'~ ~ d~ ~~ ~ p ~ ~ ~ ~ N~ ~.~-, ~ ~ ~ ~ ~~ ~~ ~ ~ ~ . ~ ~ ~ ~ ~ ~ ,~ ~ ~~ ~ N~ C ~ o~ ~ ~ ~ in~ ~ ~~ ~~ , ~ a ~ N , . ~ ~; ~, ~, ~ ~ ~, ~~ ~~ ~ v ~ °°~ a~ ~ ~ ~ ~ c~ iii ' ~ c ~. ~ ~' ~ ~ , ~ ~ ~ ~ ~ ~ 3 ~ t ~ ~ p, ~ a .~ , ~ ~ 4 ~ , • ~ ~ ~ o Y ~ ~ ~ ~ i~i~ ~, ~ i ~ , ~ , ~ ~ E v i ~ ~ ~ 3 ~ ' ~~, ~0 , 4 ~ ~ o ~ ~ ~ a o ~ , d ° ~, , a~~ ~~ , , ~ , , ~ , ~. ~ ~ ~ a~ , x ~ ~ p, °~ ~: a ~~ , ?, m , ~, ~ , I a~, E, °~~ °~~ ~ v E ~ ~ O~ ~ ~~ ~ `~. ~~ , , ~ ~ , ~ ~ , ~ ~ , ~~ ~ ~ ~~ ~, c ~ ~ , ~~ ~ ~~ , ~ ~ N~ , I V), ~. 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Z } ~- } } ~-, y- Z Z } } Z Z Z ~ ~ N ~ , ~ . ~ , ~ , ~ ~ ~ , , ~ , ~ ~ ~ ~ ~ , ~ i ~ ~ ~~ ~ , v~ ~ 5' M ~ ~ . ~ ~ ,. , ~ ~ ~ , , , , , ~ ~ ~ ~ ~ , ~ ~ , ~ ~ ~ , ~ , ~ ~ ~ , , ~ ~ , ~ +~-~ ~ ` 1, (~ , . ~ ~ ~ . ~ ~ ~ , ~ , ~ , O' G ~ , ~ ~ ~ , ~ ~ , , ~ ~ ~ , , ~ ~ , , V~ ~ ~~ ~ ~ , ~ ~ ~ . ~ ~ ~ ~ , ~ ~ ~ ~ , , , _~ E , 3, ~ , ~ ~ , , , ~ ~ , ~ . ~ ~ , . ~ ~ ~ , - , , ~ , ~ , ~, , , , , o , ~, , ~ ~ ~ y, ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ O ~ ~ , ~ , ~ ~ , ~ ~ O p' ~ , ~ ~ ~ , ~ ~ ~ ~ , ~ ~ , , V _ - ~ v, ~ ~ , ~ ~ ~ ~ ~ , ~ ~ , , ~ ~ , ~ ~ , ~ , ~ ~ ~ ~ ~ ~ ~ T ~ , ~ ~ ~ ~ , , Q . 7 ~ ~ , ~ ~ ~ ~ ~ ~ , ~ ~ ~ ~ C~ _, ~ ~ ~ ~ , , , ~ ~ ~ ~ ~ C ~ ~ . p~ ~ ~ , , 0' W ~ . ~ , ~ , ~ ~ , ~ ~ ~ ~~ ~, ~ ~ ~ ~ , ~ ~ . ~ ~ ~ , ~ ~ ~ , N~ ~ ~ , ~ x ~ U ~ ~ , ~ ~ ~ , ~ ~ , ~ ~ ~ N~ ~, ~, 'a ~ ~~ M, ~ ~ . ~ ~ , ~ ~ , ~ . ~ , ~ , ~ ~ ~ ~ , . ~ , . ~ ~ , , 3, I ~ , , U~, I ~ ~ O ~ J O ~ ~~ , ~~ ~~ ~ ~~ , ~~ ~ O ~ ~ ~ ~ ~ ~ ~ ~ - ~ ~~ ~ ! Z , ~ ~ , o, Y ~ ~, , o, Z. ~, ~~ ~ , ~ ~ ~ ~ , ~ ~ a, , a~, , , , ~ ~. ~ , ~ ~ ~, ~ ~ ~ ~ ~ ~ ~i ~ , ~ ~ ~ ~ ~ ~ ~, N~ N~ a I p) ~ . fq~ ~ . ~ ~ ~ ~ ~ ~ ~. ~ ~ y,N,, ~ . , , O, I M. . ~ ~ ~ a (~ ~ , ~ , , j, 'c o, a~, ~ I ~ a , ~ , u-, ~ ~, u, a~ \\ O ~ ' '~ ~~ 4 - ~ 4 -p~ O~ Q~ ~ ' ~ N ~ ~ ~ ~ ~~ ~ ~, ~ ~ ~~ ~~ ~A~ ~ ~ ~, ~ 1 ~ ~ ~ ~ , . ~ 'C~ N~ ~ , ~ ~ . o ~ p~ ~, ~ ~ ; -a~ a~, ~~ 7~ , ~ ,~ ~ ~ ~ , c `t~ C~ ~ ~ ~ ~ a~ ~ ~~ ~ v ~ ~ ~~ ~ eo, :~-, ~ ~~ ~ m, ~ ~~ ~ ~ ~ o. ~ V ~ ~ ~ « N ,~ i ~ ~ y ~ C ~ N ~. W ~ ~ ~ ~ pg i, •~ , ~ ~ O~ ' 3 d a, ~ M~ ~ .~~ U~ N~ N~ Q ~ ~ ~ ~ O~ ~ ~ 0, ~~~ ~~ ~~ ~ ~ N, ~ ~ ~ ~ ~ ~ ~ ~ C~ ~~ >~ , ~ , ~ =, t~ ~~ ~~ ~, ~ y, , T ~ ~, ~ Or ~ ~, 3, ~~ , ~ , Q~ ~ ~ ~ ~~ ~, ~~ ~ °tS~ "a ~. ~; ~~ 4 . , a` , ~ry -a~ ~ ~~ `~'~ ~ ~ Q~ `~ 7, ~ ~ ~~ ~~ ~~ ~~ V I Z ~ , .a o ~, a, ~ Z o~•~: -o o ~, m, fl. I ~ ~ ~ o m c~ m o o, ~ ~~ ~ a, t ~, ~ ~, ~ oS o, .. 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N fl- r- N, a~ C, J ~ ~ Q L N~ a ~. ~~~ ~~ a ' fl. y, N~ a C~~ N~ V~ ' ~' ~ ~ .~.. - ~ ~ `0 ~ ~~ a ~ E~ ` U~ N ~3, ~ ~ 3 C O , o p L, ° = i, m c ~ ~ E, ~ o, o, of ~0 ' fl, ,~, ,~ m ~ ~ ~n, , :c . oi a ~o ~o m m , cn o , oS ~ p~ ~ 2, ~, ' -a ~ o N ~ , . , - fl. -a d .~~ m c_ a Q. ~ 3 ~ ' ~' ~ ~, ar ar a~ c ~ 3~ a w ` ~ ~ ~ ~ ~ > ~ ~ Y ~ N ~ , f4 ,~ ° ~ i j ° ~ ° c~ ~ ~ a u;~ >, n a a`r °~ ~ i i U ~. a _ ~ , -a. -a -a ~ ~ m ~ s~, a ~, -Q :c, ~ ~ c a i y ~'' a a i a o .o? u, :°' c ~~ . 3 - 6 ~' v ; c ~' ai , ~ ~ ~ c ~. . . ~ O ~ ~ ~, ~ a;, o~ 3, ~ L~ G G ~ ~ E 'N,~ U, 3~°~ c6, o ~`6 `6 " °~ - , _ ? = q ~ v I o, m `° - c ~ c a~ p~ ~ m ~~ c c0, c ~ Z . '~ c m, m m a i ~, ~: o, o, ~ ~, o , o" ~ ~ cu o ~n o c~ ~, u~; o ' o~ -~ ' a;, ~ m~ ° , $. m, ~, oy vi, , ~~ ~3, ~~ ~~ , . , ~, ~ ~ a~ U ' O ~ U a~, ~; ~ . ~, ~ • ~ g - - - ~ a a~ ~ ~ ~, an ~ ~ a c m o - 3 ~ c > > c, ~ H > 3 I- F-' ~ ~ •y ~ ~, ~ ~ a~, w, ? '~ a, ~ `° o: Y ~ cLi °r ~ ~, :° N ~ m c' ~i m /~~ l >, c ~ a~, d-~, . ~~° 4 ~, °~ ~°' ~~ ~, ~' ~, tn, "_; O, 4 d a~ O, ~-' ~- ca U , ~' -~, o z ¢', ~. ~ o~, g', U; C4, U, ~', ~; U, U, m, v, U, ¢, f6 v, ~; ¢, `° •- O, "_, ~', 00, L°°' ~ C~; ~; m', ~', . m, ~, a~ a~ a, ~, tn, cn, o C~, p _ ~~ \ m a , , O r N M , , V ~(O I~ 00 m O N M~f' tn (O I~ c+0 ~ N M~Y ~ t0 I~ a0 6) C ~~° 0 ~ N M_~ ~fi (O f~ OO iA r! ~ N N N N N N N N N N _ M M M M M M M M _M V -- - ----- _~_ _ ~ ~ ~ w o ~ I o a+ p o w, p a~ V c . O C f6 ~ CV 10 (V ~ CO lp CV ~ . O p N V ~+ N ~ N O 1 6 V C '7 V O ~ ~ O ` y N T ~~ f 1v~~ N '~ Q p d ~ ~ `G "jC~ ~ ~ a ~ O U ~ ~ a E a c, a ~ cn rn W . n w a~- . , ~ , ~ a u- ~ Q cn ~ i ~ Wel( History Fi(e APPENDI~C Information of detailed nature that is not ~ panicularly geRnane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of inforrnation. ~ 1]120005162007SSN.txt Sperry-Sun Drillin9 Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Aug 10 10:15:55 2007 Reel Header Service name..... ......LISTPE Date . ...................07/08/10 Ori in ...................STS Ree~ Name. .... ........UNKNOWN Continuation tvumber......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date . ...................07/08/10 origin ...................5T5 Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................5T5 LIS Writing Library Physical EOF Comment Record TAPE HEADER west sak MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 Mw0005005556 T. GALVIN D. GLADDEN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MS~ O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD C_1 Scientific Technical Services Scientific Technical Services 1J-120 500292335200 conocoPhillips ,4laska, znc. Sperry ~rilling services 10-AUG-07 MWD RUN 3 MWD RUN 5 Mw0005005556 Mw0005005556 T. GALVIN P. ORTH D. GLADDEN D. GLADDEN 35 11N l0E 1875 2357 109.00 81.00 Page 1 aa~- -a~rs ~ ~ s3va ! 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: 171200051620075SN.txt OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 10.750 4100.0 6.750 7.625 9945.0 • l. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUNS 2,3,5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), AND GEO-PILOT ROTARY STEERABLE BHA (GP). NO DATA WERE ACQUIRED ON MWD RUN 4. 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-3,5 REPRESENT WELL 1J-120 WITH API#: 50-029-23352-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 15822'MD/3952'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). $ File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/08/10 Maximum Physical Record..65535 File Type. ............~0 Previous File Name.......5T5LIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 Page 2 . • # FILE SUMMARY 1712000516200755N.txt PBU TOOL CODE START DEPTH STOP DEPTH GR 4073.5 15764.5 FET 4085.0 15771.5 RPD 4085.0 15771.5 RPS 4085.0 15771.5 RPM 4085.0 15771.5 RPx 4085.0 15771.5 ROP 4110.5 15822.0 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 4073.5 4283.0 MwD 3 4283.0 9966.0 MwD 5 9966.0 15822.0 $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type... ..........0 ~ata specification Block Type.....0 l.og~ing Direction .................DOwn Optical log depth units...........Feet ~ata Reference Point ..............Undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units Datum specification Block sub-type...0 Name Service order units size Nsam rtep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4073.5 15822 9947.75 23498 4073.5 15822 RPD MWD OHMM 0.28 2000 19.926 23374 4085 15771.5 RPM MwD OHMM 0.08 2000 16.3867 23374 4085 15771.5 RPS Mw~ OHMM 4.07 2000 15.6779 23374 4085 15771.5 RPx MwD OHMM 3.66 2000 14.7727 23374 4085 15771.5 FET MWD HOUR 0.16 108.47 1.26073 23374 4085 15771.5 GR Mw~ API 21.13 121.8 70.0481 23383 4073.5 15764.5 ROP MwD FT/H 0.29 552.24 192.691 23424 4110.5 15822 Page 3 • ~ 17120005162007SSN.tx~t First Reading For Entire File..........4073.5 Last Reading For Entire File...........15822 File Trailer Service name. .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/08/10 Maximum Physical Record..65535 File Ty e ................LO Next F~~e Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/10 Maximum Physi~al Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4073.5 4245.5 FET 4085.0 4232.5 RPx 4085.0 4232.5 RPS 4085.0 4232.5 RPM 4085.0 4232.5 RPD 4085.0 4232.5 ROP 4110.5 4283.0 $ # LOG HEADER DATA DATE LOGGED: 06-MAY-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 4283.0 TOP LOG INTERVAL (FT): 4110.0 BOTTOM LOG INTERVAL (FT): 4283.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 72.3 MAXIMUM ANGLE: 72.7 # TOOL STRING (TOP TO BOTfOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 053516 Page 4 ~ ~ 1.712000516200755N.txt EWR4 ELECTROMAG. RESIS. 4 81390 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 4100.0 # BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (5): 41.0 MUD PH: 8.6 MUD CHLORIDES (PPM): 250 FLUID LO55 (C3): 6.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 4.500 65.0 MUD AT MAX CIRCULATING TERMPERATURE: 4.320 68.0 MUD FILTRATE AT MT: 5.400 65.0 MUD CAKE AT MT: 3.200 65.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Log~ing Direction .................Down Optical log depth units...........Feet ~ata Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record ...........:.undefined ,4bsent value ......................-999 Depth Units. . .. .. ..... Datum Specification Block sub-type...0 Name Service Order units Size Nsam rtep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4073.5 4283 4178.25 420 4073.5 4283 RPD MwD020 OHMM 3.32 2000 134.831 296 4085 4232.5 RPM MWD020 OHMM 6.93 1550.53 37.5355 296 4085 4232.5 RPS Mw~020 OHMM 5.62 1733.57 31.207 296 4085 4232.5 RPx MwD020 OHMM 3.66 1729.16 21.3865 296 4085 4232.5 FET MwD020 HOUR 0.16 69.4 13.4449 296 4085 4232.5 Page 5 . ~ 1~120005162007s5N.txt GR MWD020 API 42.35 99.3 65.3099 345 4073.5 ROP MwD020 FT/H 27.58 418.49 252.325 346 4110.5 First Reading For Entire File..........4073.5 ~ast Reading For Entire File...........4283 File Trailer Service name... .......STSLIB.002 Service Sub Level Name... version tvumber. ........1.0.0 Date of Generation.......07/08/10 Maximum Physical Record..65535 File Ty e ................LO Next Fi~e Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/OS/10 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.002 Comment Record FTLE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 4233.0 9915.0 RP5 4233.0 9915.0 RPx 4233.0 9915.0 RPM 4233.0 9915.0 RPD 4233.0 9915.0 GR 4246.0 9928.5 ROP 4283.5 9966.0 $ # LOG HEADER DATA DATE LOGGED: 09-MAY-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9966.0 TOP LOG INTERVAL (FT): 4283.0 BOTTOM LOG INTERVAL (FT): 9966.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 72.6 MAXIMUM ANGLE: 83.6 # Page 6 4245.5 4283 ! • 1712000516200755N.txt TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124724 EWR4 ELECTROMAG. RESIS. 4 157645 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 4100.0 # # # # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LO55 (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: # Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Log~ing Direction .................Down optical log depth units...........Feet ~ata Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 ~epth units. . .. .. ..... ~atum Specification Block sub-type...0 Polymer 9.10 39.0 9.2 200 2.0 3.800 65.0 2.550 100.4 4.500 65.0 3.100 65.0 Name service Order Units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4233 9966 7099.5 11467 4233 9966 RPD MwD030 OHMM 4.17 1 39.64 13.5498 11365 4233 9915 RPM MwD030 OHMM 4.38 82.84 12.4921 11365 4233 9915 Page 7 ~ 1~1200051620075SN.txt ~~ RPS MwD030 OHMM 4.07 94.89 12.2617 11365 4233 9915 RPx MWD030 OHMM 3.98 2000 12.442 11365 4233 9915 FET MwD030 HOUR 0.16 8.74 0.663894 11365 4233 9915 GR Mw~030 API 21.13 115.83 70.1211 11366 4246 9928.5 ROP MwD030 FT/H 1.25 552.24 200.027 11366 4283.5 9966 First Reading For Entire File..........4233 ~ast Reading For Entire File...........9966 File Trailer Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/08/10 Maximum Physical Record..65535 File TyPe ................LO Next File Name...........STSLIB.004 Phy5iCd1 EOF File Header Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/08/10 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 9915.5 15771.5 RPx 9915.5 15771.5 RPD 9915.5 15771.5 FET 9915.5 15771.5 RPS 9915.5 15771.5 GR 9929.0 15764.5 ROP 9966.5 15822.0 $ # LOG HEADER DATA DATE LOGGED: 16-MAY-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRI~LER (FT): 15822.0 TOP LOG INTERVAL (FT): 9966.0 BOTTOM LOG INTERVAL (FT): 15822.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG Page 8 . , • ~ 1]12000516200755N.txt MINIMUM ANGLE: 86.3 MAXIMUM ANGLE: 92.8 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156435 EwR4 Electromag Resis. 4 73634 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 9945.0 # # # # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LO55 (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type... ..........0 ~ata specification Block Type.....0 Log~ing Direction .................Down optical log depth units...........Feet Data rteference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. .. ..... Datum specification Block sub-type...0 Name service order DEPT RPD MWD050 RPM MWD050 RPS MWD050 RPX MWD050 FET MWD050 GR MWD050 ROP MWD050 Name Service Unit Mineral Oil Base 8.40 63.0 .0 21500 15.8 .000 .0 .000 111.0 .000 .0 .000 .0 units size rvsam Rep code offset channel FT 4 1 68 0 1 OHMM 4 1 68 4 2 OHMM 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 HOUR 4 1 68 20 6 API 4 1 68 24 7 FT/H 4 1 68 28 8 First Last Min Max Mean Nsam Reading Reading Page 9 ~ . 1.712000516200755N.txt DEPT FT 9915.5 15822 12868.8 11814 9915.5 15822 RPD MwD050 OHMM 0.28 2000 23.2089 11713 9915.5 15771.5 RPM MwD050 OHMM 0.08 2000 19.6311 11713 9915.5 15771.5 RPS MwD050 OHMM 4.77 2000 18.6002 11713 9915.5 15771.5 RPx MWD050 OHMM 4.17 2000 16.8669 11713 9915.5 15771.5 FET Mw~050 HOUR 0.2 108.47 1.53193 11713 9915.5 15771.5 GR MwD050 API 38.66 121.8 70.1171 11672 9929 15764.5 ROP MwD050 FT/H 0.29 366.03 183.81 11712 9966.5 15822 First Reading For Entire File..........9915.5 Last Reading For Entire File...........15822 File Trailer Service name... .......STSLIB.004 Service Sub Level~Name... version Number. ........1.0.0 ~ate of Generation.......07/08/10 Maximum Physical Record..65535 File Type ................LO Next File Name...........5T5LIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................07/08/10 Origin ...................5T5 Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................5T5 LIS Writing Library Reel Trailer Service name .............LISTPE Date . ...................07/08/10 Ori in ...................STS Ree~ Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library Phy5iCd1 EOF Physical EOF End Of LIS File Scientific Technical Services Scientific Technical services Page 10
