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199-001
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: SUSP Renewal 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11061' None Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 11/20/2025 3-1/2" Packer: Baker 80-40 Casing Seal Assmby SSSV: None Perforation Depth MD (ft): L-80 3217' 10585-10595', 10610-10650' cemented 11008' 5113-5119', 5127-5149' cemented 5-1/2" x 3-1/2" Perforation Depth TVD (ft): 119' 3251' 5372'11041' 16" 7-5/8" 76' 7946' MD 119' 2310' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Tarn Oil Pool - Suspended TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0380054 199-001 P.O. Box 100360, Anchorage, AK 99510 50-103-20287-00-00 Kuparuk River Field Tarn Oil Pool- Suspended AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 10264' MD and 4936' TVD N/A Dusty Freeborn Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: Dusty.Freeborn@conocophillips.com (907) 265-6218 Staff Well Integrity Engineer KRU 2N-320 5384' 7968' 4013' Plugs (MD): 7968' Burst N/A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Dusty Freeborn DN: CN=Dusty Freeborn, O=ConocoPhillips Alaska, OU=Well Integrity and Intervention, E=Dusty.Freeborn@ conocophillips.com, C=US Reason: I am the author of this document Location: Anchorage, Alaska Date: 2025.11.19 13:05:43-09'00' Foxit PDF Editor Version: 13.1.6 Dusty Freeborn 325-710 By Grace Christianson at 4:03 pm, Nov 19, 2025 November 30, 2030 TS 11/20/25J.Lau 11/20/25 11/21/25 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 19, 2025 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Suspended Well Renewal 10-403 Sundry KRU 2N-320 (PTD 199-001) Dear Commissioner Chmielowski: ConocoPhillips Alaska Inc. hereby submits a request for renewal of the suspension status of Kuparuk River Unit 2N-320 (PTD 199-001) per 20 AAC 25.110. The request to re- suspend is to preserve the wellbore as it is currently the best candidate to access 2N- Yorktown. The 2N-Yorktown is part of the portfolio of future Tarn sidetrack opportunities. The current condition of the well is noted on an attached schematic and 10-403 form. Please note the following: - The wells perforations have been isolated with a cement plug. - The well is on an active pad (2N-pad) associated with lease number ADL0380054. - There are no known abnormal geo-pressured or depleted strata. Last know bottom hole pressure was measured at 2601 psi on 5th Oct 2015 prior to cement application to perforations. - The well bore traverses the following lease numbers which are within the KRU, therefore held by the unit; ADL 380054 (expiration 31 Jan 2003) and ADL 375074 (expiration 31 March 2001). Please call me at (907) 265-6218 if you have any questions. Sincerely, Dusty Freeborn Well Integrity Engineer ConocoPhillips Alaska, Inc. Digitally signed by Dusty Freeborn DN: CN=Dusty Freeborn, O=ConocoPhillips Alaska, OU=Well Integrity and Intervention, E =Dusty.Freeborn@conocophillips.com, C=US Reason: I am the author of this document Location: Anchorage, Alaska Date: 2025.11.19 13:06:04-09'00' Foxit PDF Editor Version: 13.1.6 Dusty Freeborn Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.062 Top (ftKB) 42.8 Set Depth (ftKB) 119.0 Set Depth (TVD) 119.0 Wt/Len (l 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 7 5/8 ID (in) 6.875 Top (ftKB) 34.6 Set Depth (ftKB) 3,251.2 Set Depth (TVD) 2,309.9 Wt/Len (l 29.70 Grade L-80 Top Thread BTC-MOD Casing Description PRODUCTION 5.5"x3.5" @ 10277' OD (in) 5 1/2 ID (in) 4.950 Top (ftKB) 33.0 Set Depth (ftKB) 11,040.5 Set Depth (TVD) 5,371.9 Wt/Len (l 15.50 Grade L-80 Top Thread MOD Tubing Strings Tubing Description TUBING KILL STRING 2015 RWO String Ma 3 1/2 ID (in) 2.992 Top (ftKB) 30.4 Set Depth (ft 7,946.4 Set Depth (TVD) ( 4,006.6 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 30.4 30.4 0.09 HANGER FMC TC-1A-EMS, 11" x 3-1/2", EUE 8rd Top and Bottom, 7.115" OD EN, 2.992 Tubing Description TUBING String Ma 3 1/2 ID (in) 2.992 Top (ftKB) 9,833.0 Set Depth (ft 10,280.0 Set Depth (TVD) ( 4,945.3 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rdMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 10,153.1 4,877.0 58.26 SLEEVE-C BAKER CMU SLIDING SLEEVE w/CAMCO PROFILE (CLOSED 1/12/2006) 2.813 10,254.8 4,931.6 56.96 NIPPLE CAMCO 'D' NIPPLE 2.750 10,262.0 4,935.5 56.92 LOCATOR BAKER LOCATOR - SITS 1' ABOVE PROD CSG CSR 2.985 10,263.5 4,936.3 56.91 SEAL ASSY BAKER 5.5" 80-40 CASING SEAL ASSEMBLY 2.985 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 8,283.0 4,118.4 69.51 Cement Retainer BAKER 2AA 12/15/2015 CONDUCTOR SUBSIDENCE: Welded 11"x16" extension on top of existing conductor; raising back to original RKB 9/2/2013 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Zone Date Shot Dens (shots/f t)Type Com 10,585.0 10,595.0 5,112.9 5,118.5 S-5, 2N-320 11/13/2006 6.0 APERF 2.5" HSD BH, 60 deg phase 10,610.0 10,650.0 5,126.8 5,149.1 S-3, 2N-320 3/5/1999 4.0 IPERF 2.5" HC BHC, 180 deg phase, orient +/-90 deg from high side Stimulations & Treatments Min Top Depth (ftKB) Max Btm Depth (ftKB)Top (TVD) (ftKB) Btm (TVD) (ftKB) Type Date Com 10,610.0 10,650.0 5,126.8 5,149.1 FRAC 3/14/1999 PLACED 93,000# PROPPANT IN FORMATION 10,585.0 10,617.0 5,112.9 5,130.7 FRAC 1/16/2008 PLACED TOTAL OF 186,000# OF 16/20 CERAMIC PROPPANT BEHIND PIPE W/9 PPA ON PERFS Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Start Date Com 8,233.0 10,650.0 4,100.8 5,149.1 Cement Squeeze 12/15/201 5 ALL PERFS CEMENTED DURING 2015 RWO 7,967.7 10,650.0 4,013.3 5,149.1 Cement Squeeze 12/15/201 5 ALL PERFS CEMENTED DURING RWO 2015 Notes: General & Safety End Date Annotation 7/17/2009 NOTE: View Schematic w/ Alaska Schematic9.0 Comment SSSV: NONE2N-320, 1/12/2016 12:36:08 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 10277'; 33.0-11,040.5 FRAC; 10,610.0 IPERF; 10,610.0-10,650.0 FRAC; 10,585.0 APERF; 10,585.0-10,595.0 SEAL ASSY; 10,263.5 LOCATOR; 10,262.0 NIPPLE; 10,254.8 GAS LIFT; 10,203.1 SLEEVE-C; 10,153.1 TUBING; 9,833.0 Cement Retainer; 8,283.0 SURFACE; 34.6-3,251.2 CONDUCTOR; 42.8-119.0 HANGER; 30.4 Annotation Last Tag: SLM Depth (ftKB) 9,728.0 End Date 5/31/2013 Annotation Rev Reason: WORKOVER; WELL SUSPENDED Last Mod By lehallf End Date 1/8/2016 KUP PROD KB-Grd (ft) 42.76 Rig Release Date 2/12/1999 Annotation Last WO: End Date 12/20/2015 2N-320 H2S (ppm) 67 Date 3/13/2015 ... TD Act Btm (ftKB) 11,061.0 Well Attributes Wellbore API/UWI 501032028700 Field Name TARN PARTICIPATING AREA Wellbore Status PROD Max Angle & MD Incl (°) 72.23 MD (ftKB) 7,891.01 2N-320 365-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Lau, Jack J (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL]KRU 2N-320 (199-001) Suspension Date:Thursday, November 20, 2025 2:13:27 PM Attachments:image001.png AnnComm Surveillance TIO for 2N-320.pdf From: Freeborn, Dusty <Dusty.Freeborn@conocophillips.com> Sent: Thursday, November 20, 2025 12:40 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: RE: [EXTERNAL]KRU 2N-320 (199-001) Suspension Hey Jack- No indications of SCP. The attached 365-day TIO plot indicates stable IA & OA pressures. Tubing has remained 0 psi since original suspension. The OA was last noted at 200 psi which is within the expected pressure seen through out the well’s life. Dusty Freeborn Well Integrity Engineer ConocoPhillips Alaska, Inc. Office phone: (907) 265-6218 Cell phone: (907) 830-9777 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Thursday, November 20, 2025 11:22 AM To: Freeborn, Dusty <Dusty.Freeborn@conocophillips.com> Subject: [EXTERNAL]KRU 2N-320 (199-001) Suspension CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Dusty - Quick question, was there any sign of sustained question pressure? TIO look normal? Jack Lau Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission (907) 793-1244 Office (907) 227-2760 Cell 2N-320 365-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11061'feet 7967'feet true vertical 5384' feet None feet Effective Depth measured 7967'feet None feet true vertical 4013' feet None feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 10280' MD 4945' TVD Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Tarn Oil Pool - SUSPENDED 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: 3251' 2310' Burst Collapse Production Liner 10256' 753' Casing 4935' 3-1/2" 10277' 11040' 5371' 3217' 119'Conductor Surface Intermediate 16" 7-5/8" 76' measured TVD 5-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 199-001 50-103-20287-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0380054 Kuparuk River Field/ Tarn Oil Pool KRU 2N-320 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 119' ~~~ SUSPENDED ~~ ~ N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A None Dusty Freeborn Dusty.Freeborn@conocophillips.com 907-659-7224Staff Well Integrity Engineer 7968-10650' Cemented 4013-5149' Cemented Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 9:12 am, Sep 26, 2025 Digitally signed by Dusty Freeborn DN: CN=Dusty Freeborn, O=ConocoPhillips Alaska, OU=Well Integrity and Intervention, E=Dusty.Freeborn @conocophillips.com, C=US Reason: I am the author of this document Location: Anchorage, Alaska Date: 2025.09.24 11:12:04-08'00' Foxit PDF Editor Version: 13.1.6 Dusty Freeborn RBDMS JSB 100225 J.Lau 11/5/25 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 8, 2025 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Suspended Well Inspection 10-404 Sundry KRU 2N-320 (PTD 199-001) Dear Commissioner Chmielowski: Enclosed please find the suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. Kuparuk River Unit well 2N-320 (PTD 199-001). The following documents are attached: - 10-404 Sundry - Suspended Well Inspection - Wellbore Schematic - Location Plot Plan - Photographs Please call me at (907) 265-6218 if you have any questions. Sincerely, Dusty Freeborn Well Integrity Engineer ConocoPhillips Alaska, Inc. Digitally signed by Dusty Freeborn DN: CN=Dusty Freeborn, O=ConocoPhillips Alaska, OU=Well Integrity and Intervention, E =Dusty.Freeborn@conocophillips.com, C=US Reason: I am the author of this document Location: Anchorage, Alaska Date: 2025.09.24 11:12:27-08'00' Foxit PDF Editor Version: 13.1.6 Dusty Freeborn Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.062 Top (ftKB) 42.8 Set Depth (ftKB) 119.0 Set Depth (TVD) … 119.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 7 5/8 ID (in) 6.875 Top (ftKB) 34.6 Set Depth (ftKB) 3,251.2 Set Depth (TVD) … 2,309.9 Wt/Len (l… 29.70 Grade L-80 Top Thread BTC-MOD Casing Description PRODUCTION 5.5"x3.5" @ 10277' OD (in) 5 1/2 ID (in) 4.950 Top (ftKB) 33.0 Set Depth (ftKB) 11,040.5 Set Depth (TVD) … 5,371.9 Wt/Len (l… 15.50 Grade L-80 Top Thread MOD Tubing Strings Tubing Description TUBING KILL STRING 2015 RWO String Ma… 3 1/2 ID (in) 2.992 Top (ftKB) 30.4 Set Depth (ft… 7,946.4 Set Depth (TVD) (… 4,006.6 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE 8rd Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 30.4 30.4 0.09 HANGER FMC TC-1A-EMS, 11" x 3-1/2", EUE 8rd Top and Bottom, 7.115" OD EN, 2.992 Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.992 Top (ftKB) 9,833.0 Set Depth (ft… 10,280.0 Set Depth (TVD) (… 4,945.3 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rdMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 10,153.1 4,877.0 58.26 SLEEVE-C BAKER CMU SLIDING SLEEVE w/CAMCO PROFILE (CLOSED 1/12/2006) 2.813 10,254.8 4,931.6 56.96 NIPPLE CAMCO 'D' NIPPLE 2.750 10,262.0 4,935.5 56.92 LOCATOR BAKER LOCATOR - SITS 1' ABOVE PROD CSG CSR 2.985 10,263.5 4,936.3 56.91 SEAL ASSY BAKER 5.5" 80-40 CASING SEAL ASSEMBLY 2.985 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 8,283.0 4,118.4 69.51 Cement Retainer BAKER 2AA 12/15/2015 CONDUCTOR SUBSIDENCE: Welded 11"x16" extension on top of existing conductor; raising back to original RKB 9/2/2013 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Zone Date Shot Dens (shots/f t)Type Com 10,585.0 10,595.0 5,112.9 5,118.5 S-5, 2N-320 11/13/2006 6.0 APERF 2.5" HSD BH, 60 deg phase 10,610.0 10,650.0 5,126.8 5,149.1 S-3, 2N-320 3/5/1999 4.0 IPERF 2.5" HC BHC, 180 deg phase, orient +/-90 deg from high side Stimulations & Treatments Min Top Depth (ftKB) Max Btm Depth (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Type Date Com 10,610.0 10,650.0 5,126.8 5,149.1 FRAC 3/14/1999 PLACED 93,000# PROPPANT IN FORMATION 10,585.0 10,617.0 5,112.9 5,130.7 FRAC 1/16/2008 PLACED TOTAL OF 186,000# OF 16/20 CERAMIC PROPPANT BEHIND PIPE W/9 PPA ON PERFS Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Start Date Com 8,233.0 10,650.0 4,100.8 5,149.1 Cement Squeeze 12/15/201 5 ALL PERFS CEMENTED DURING 2015 RWO 7,967.7 10,650.0 4,013.3 5,149.1 Cement Squeeze 12/15/201 5 ALL PERFS CEMENTED DURING RWO 2015 Notes: General & Safety End Date Annotation 7/17/2009 NOTE: View Schematic w/ Alaska Schematic9.0 Comment SSSV: NONE2N-320, 1/12/2016 12:36:08 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 10277'; 33.0-11,040.5 FRAC; 10,610.0 IPERF; 10,610.0-10,650.0 FRAC; 10,585.0 APERF; 10,585.0-10,595.0 SEAL ASSY; 10,263.5 LOCATOR; 10,262.0 NIPPLE; 10,254.8 GAS LIFT; 10,203.1 SLEEVE-C; 10,153.1 TUBING; 9,833.0 Cement Retainer; 8,283.0 SURFACE; 34.6-3,251.2 CONDUCTOR; 42.8-119.0 HANGER; 30.4 Annotation Last Tag: SLM Depth (ftKB) 9,728.0 End Date 5/31/2013 Annotation Rev Reason: WORKOVER; WELL SUSPENDED Last Mod By lehallf End Date 1/8/2016 KUP PROD KB-Grd (ft) 42.76 Rig Release Date 2/12/1999 Annotation Last WO: End Date 12/20/2015 2N-320 H2S (ppm) 67 Date 3/13/2015 ... TD Act Btm (ftKB) 11,061.0 Well Attributes Wellbore API/UWI 501032028700 Field Name TARN PARTICIPATING AREA Wellbore Status PROD Max Angle & MD Incl (°) 72.23 MD (ftKB) 7,891.01 “Copyright 2025. All rights reserved. This photograph is provided to the AOGCC with permission to copy for its own use. Copying for any other purpose or by any other party is prohibited without the express consent of ConocoPhillips Alaska, Inc.” “Copyright 2025. All rights reserved. This photograph is provided to the AOGCC with permission to copy for its own use. Copying for any other purpose or by any other party is prohibited without the express consent of ConocoPhillips Alaska, Inc.” “Copyright 2025. All rights reserved. This photograph is provided to the AOGCC with permission to copy for its own use. Copying for any other purpose or by any other party is prohibited without the express consent of ConocoPhillips Alaska, Inc.” “Copyright 2025. All rights reserved. This photograph is provided to the AOGCC with permission to copy for its own use. Copying for any other purpose or by any other party is prohibited without the express consent of ConocoPhillips Alaska, Inc.” “Copyright 2025. All rights reserved. This photograph is provided to the AOGCC with permission to copy for its own use. Copying for any other purpose or by any other party is prohibited without the express consent of ConocoPhillips Alaska, Inc.” Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 10/29/2025 InspectNo:susSTS250908114636 Well Pressures (psi): Date Inspected:9/6/2025 Inspector:Sully Sullivan If Verified, How?Other (specify in comments) Suspension Date:12/18/2015 #315-742 Tubing:0 IA:0 OA:200 Operator:ConocoPhillips Alaska, Inc. Operator Rep:Matt Miller Date AOGCC Notified:9/3/2025 Type of Inspection:Subsequent Well Name:KUPARUK RIV U TARN 2N-320 Permit Number:1990010 Wellhead Condition Good condition, valves turn easily, wellhead is in a well house Surrounding Surface Condition clean, no subsidence Condition of Cellar clear water in cellar with no sheen or trash Comments Gauges were accurate and verified by calibrated digital gauge. Location was verified by plot map. Supervisor Comments Photos (3) attached Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Wednesday, October 29, 2025 2025-0906_Suspend_KRU_2N-320_photos_ss Page 1 of 2 Suspended Well Inspection – KRU 2N-320 PTD 1990010 AOGCC Inspection Rpt # susSTS250908114636 Photos by AOGCC Inspector S. Sullivan 9/6/2025 2025-0906_Suspend_KRU_2N-320_photos_ss Page 2 of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y Samantha Carlisle at 9:58 am, Jun 15, 2020 Digitally signed by jan.byrne@conocophillips.com DN: CN=jan.byrne@conocophillips.com Reason: I am the author of this document Location: Kuparuk, F-wing, F-217 Date: 2020-06-12 10:56:44 Foxit PhantomPDF Version: 9.7.0 jan.byrne@conocophilli ps.com DSR-6/15/2020 SFD 6/17/2020 RBDMS HEW 6/15/2020 -00 VTL 7/27/20 Digitally signed by jan.byrne@conocophillips.com DN: CN=jan.byrne@conocophillips.com Reason: I am the author of this document Location: Kuparuk, F-wing, F-217 Date: 2020-06-12 10:56:18 Foxit PhantomPDF Version: 9.7.0 jan.byrne@co nocophillips.c om # !'A $% , "$% 54,3 $& '% 731 $& '% 24 $%( 24 )$( ,351 *+ E#74 + "(/'(' # A ( $% -561 "$% ,1-5 $& '% +7, $& '% +&353 $%( 3&+422 )$( 32-4 *+ /#14 + ; #8' # 'A $! 55F)+5FC43--G $% 563 "$% 7254 $& '% ++4 $& '% &4745 $%( 5&+-2 )$( 554 *+ /#14 + 8' , ,# A;$!=<$// $!=345 " ( +63 "$% 3223 $& '% +47 $& ( -&27,7 $%$( 7&44,, $,)& % 2+4 *+ /#14 # (A(1 - $& '% $%$& '% "#$.% " - - -" $% +47 +47 442 E!=( 8 ##(8&F)+#63F&(A(1 ; & -5F'(!& 3223 ,# A;$!= ( +63 "$% 3223 $& '% 2&1++4 $& ( 4&3144 $%$( 7&275+ $,)& % 2+4 *+ /#14 # (A(18' - $& '% $%$& '% "#$.% " - - -" $% 4&5+ 7&1--4 513, /((9(# ;<( 8A/$'$!=/((9( 6 8 $/( . /('636344,0 31+ 4&3571 7&2+, 5,2, !$/( 8 G'G!$/( 3-54 4&3,34 7&2+55 5,23 / ;<( / #$G;9( ' = 3215 4&3,+5 7&2+,+ 5,2 (/> ;<( 55F14#74 $!=(/(8;/> 3215 "/$ 0,1001-1& 1 #2% $& '% $% $& '% "# $.% - "$% 1&31+4 7&17 ,25 ;<( 3 3656345 !'A A;$'(! 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" 544+3431-44 + - ! $ $$!= ( , ' 6!3 "#$.% -33+ $& '% -&124 Suspended Well Inspection Review Report InspectNo: susBDB200517132555 Date Inspected: 5/16/2020 Inspector: Brian Bixby Type of Inspection Well Name: KUPARUK RIV U TARN 2N-320 I Permit Number: 1990010 Suspension Approval Sundry Suspension Date: 12/18/2015 Location Verified? W a 315-742 ` If Verified, How? Other (specify in comments) Offshore? ❑ Subsequent Date AOGCC Notified: 4/27/2020 Operator: ConocoPhillips Alaska, Inc. Operator Rep: Roger Winter Wellbore Diagram Avail? C Photos Taken? Well Pressures (psi): Tubing: 0 - Fluid in Cellar? ❑ IA: 0 BPV Installed? ❑ 0A: 200 VR Plug(s) Installed? ❑ Wellhead Condition The wellhead looked to be in good condition and all the valves worked properly and had gauges on them. Condition of Cellar Good SarroundlnF., Surface Condition The surrounding area in wellhouse looked to be in good order. No signs of any leaks and clean of any trash. Outside snow covered Coinrnenis Location Verified by as -built pad map. Su pervlsor Comments Photos (3). Location should be free of ice and snow for suspended well inspection. Friday, June 5, 2020 l �� , 2020-0516_Suspend_KRU_2N-320_photos_bb.docx Page 2 of 2 STATE OF ALASKA ALADA OIL AND GAS CONSERVATION COMI.ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed. Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: Suspended Inspect (� 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 199-0010 3.Address: 6.API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service r 50-103-20287-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 0380054 KRU Tarn 2N-320 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Kuparuk River Field/Tarn Oil Pool 11.Present Well Condition Summary: Total Depth measured 11061 feet Plugs(measured) 7967, 8283 true vertical 5384 feet Junk(measured) 9833' Effective Depth measured 7967 feet Packer(measured) 10264 true vertical 4013 feet (true vertical) 4936 Casing Length Size MD ND Burst Collapse CONDUCTOR 76' 16 119' 119' SURFACE 3217' 7 5/8 3251' 2310' Production 10256' 51/2 10277' 4935' Liner 753' 31/2 11040' 5371' °� E E6 D Perforation depth: Measured depth: Cemented jU�.. 9 201 True Vertical Depth: Cemented SCANNED D ` `' AOGCC Tubing(size,grade,MD,and TVD) 3 1/2 ,L-80, 7946 MD,4006 TVD Packers&SSSV(type,MD,and ND) No SSSV SEAL ASSY=BAKER 5.5"80-40 CASING SEAL ASSEMBLY @ 10264 MD and 4936 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): NA Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: NA Contact MJ Loveland Email: n1878(a conocophillips.com Printed Name MJ Loveland Title: NSK Well Integrity Project Supervisor Signature !' Phone:659-7043 Date 07/16/16 '—e"-/ Ve. 1 3 i 1 11 Form 10-404 Revised 5/2015 Submit Original Only RBDMS 01 JUL 2 2 2016 • • • • ConocoPhill ps Alaska E EI vE0 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 JUL 19 2016 July 16, 2016 AOGCC Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Suspended Well Inspection 10-404 Sundry Tarn/Kuparuk River Unit 2N-320 (PTD 199-001) Dear Commissioner Foerster: Enclosed please find the initial required suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. Tarn/Kuparuk River Unit 2N-320 (PTD 199-001). This well was suspended during an unsuccessful rig workover in December 2015. It is suspended with a cement retainer and cement plug across the perforations, seal assembly, and up into the original tubing stub. An open ended tubing work string was run to 7946'. The IA has maintained zero pressure indicating barrier integrity. The motherbore is being preserved for future sidetrack opportunities. The following documents are attached: - 10-404 Sundry - Suspended Well Site Inspection Form - Wellbore Schematic - Location Plot Plan - Photographs Please call me at 659-7043 if you have any questions. Sincerely, .177 77 MJ Love and ConocoPhillips Alaska Well Integrity Projects Supervisor Enclosures Suspend&fell Site Inspection Form • Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: KRU TARN 2N-320 Field/Pool: Tarn/KRU Permit# (PTD): 199-001 API Number: 501032028700 Operator: ConocoPhillips Alaska, Inc. Date Suspended: 12/18/2015 Surface Location: 57 FNL 748 FEL Section: 3 Township: 9N Range: 7E Nearest active pad or road: 2N Meridian: UM Take to Location Digital camera Map showing well location/Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: 2N Pad -Clean well row with gravel pad Pad or location surface: Gravel in good condition Location cleanup needed: none Pits condition: NA Surrounding area condition: Gravel in good condition Water/fluids on pad: Dry Pad Discoloration, Sheens on pad, pits or water: NA Samples taken: None Access road condition: Rig Mats on Road from recent rig move Photographs taken (#and description): Photos take of front and back of Well house Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2)well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: Good well head tree and valve condition Cellar description, condition, fluids: Wet gravel in cellar, gas bubbing in conductor every—10-seconds Rat Hole: NA Wellhouse or protective barriers: Well house in place Well identification sign: Well sign on front of well house Tubing Pressure (or casing if no tubing): Not Available- BPV installed, but tubing open ended Annulus pressures: IA(and tubing) = 0 psi, OA= 170 PSI Wellhead Photos taken (#and description): Several photos take of the valves gages, well head and tree Work Required: None Operator Rep (name and signature): MJ Loveland AOGCC Inspector: Guy Cook Other Observers: Roger Mouser Inspection Date: 7/16/2016 AOGCC Notice Date: 7/5/2016 Time of arrival: 1:30 PM Time of Departure: 2:00 PM Site access method: Truck - KUP PROD • 2N-320 ConocoPhillips s Well Attributes Max Angle&MD TD Alaska inc. Wellbore API/UWI Field Name Wellbore Status lIncl(°) MD(ftKB) Act Bim(ftKB) " oPrsnpc 501032028700 TARN PARTICIPATING AREA PROD 72.23 7,891.01 11,061.0 --- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) 'i Rig Release Date 2N-320,1/12/2016 12:36:08 PM SSSV:NONE 67 3/13/2015 Last WO: 12/20/2015 42.76 2/12/1999 Vertical schemata(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 9,728.0 5/31/2013 Rev Reason:WORKOVER;WELL SUSPENDED lehallf 1/8/2016 .__................................................ HANGER;30.4- ' >4 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread • CONDUCTOR 16 15.062 42.8 119.0 119.0 62.58 H-40 WELDED • Casing Description OD(in) ID(in) Top(ftKB) Sat Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread 1 I SURFACE 7 5/8 6.875 34.6 3,251.2 2,309.9 29 70 L-80 BTC-MOD Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len ft...Grade Top Thread I PRODUCTION 5 1/2 4.950 33.0 11,040.5 5,371.9 15.50 L-80 MOD I ■ 5.5"x3.5"@ 10277' I 1 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...(Wt(Ibffl) Grade Top Connection 11- ' TUBING KILL 31/2 2.992 30.4 7,946.4 4,006.6 9.30 L-80 EUE 8rd STRING 2015 RWO Completion Details LIW14alm.. ,. :: Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) hem Des Corn FMC TC-IA-EMS,11"x 3-11 (in) 30.4 30.4 0.09 HANGER 2",EUE 8rd Top and Bottom, 2.992 N' -nCONDUCTOR;42.8-119.0• �M-- 7.115"OD EN, Tubing Description !String Ma...I ID(in) 'Top(ftKB) iSet Depth(ft..J Set Depth(TVD)(...IWt(Ib/ft) 'Grade 'Top Connection TUBING 31/2 2.992 9,833.0 10,280.011 4,9453 9.30 L-80 EUEBrd MOD Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) 10,153.1 4,877.0 5826 SLEEVE-C 'BAKER CMU SLIDING SLEEVE w/CAMCO PROFILE 2.813 (CLOSED 1/12/2006) 10,254.8 4,931.6 56.96 NIPPLE CAMCO'D'NIPPLE 2.750 10,262.0 4,935.5- 56.92 LOCATOR BAKER LOCATOR-SITS 1'ABOVE PROD CSG CSR ' 2.985 ' 10,263.5 4,936.3 56.91 SEAL ASSY BAKER 5.5"80-40 CASING SEAL ASSEMBLY 2.985 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) SURFACE;34.8-3,251.2 + ' Top(ND) Top Incl Top(ftKB) (ftKB) 1') Des Corn Run Date ID(in) 8,283.0 4,118.4 69.51 Cement BAKER2AA 12/15/2015 - Retainer NM 'CONDUCTOR SUBSIDENCE:Welded 11"x16" 9/2/2013 M extension on top of existing conductor,raising back 07 to original RKB Cement Retainer;8,283.0 , Perforations&Slots '; � Shot <M' Dens <Mv Top(TVD) atm(TVD) (ehots/f � ,. Top(ftKB) 131m(ftKB) (ftKB) (ftKB) Zone Date t) Type Com <Ms; 10,585.0 10,595.0 5,112.9 5,118.5 S-5,2N-320 11/13/2006 6.0 APERF 2.5"HSD BH,60 deg TUBING:5,833.0 ?M., phase am\ r\i\ 10,610.0 10,650.0 5,126.8 5,149.1 S-3,2N-320 3/5/1999 4.0 !PERF 2.5"HC BHC,180 deg SLEEVE-C;10,153.1 -�MA. phase,orient+1-90 deg < \ from high side '. \ Stimulations&Treatments • \' Min Top Max Btm \ Depth Depth Top(TVD) Btm(TVD) > \ (ftKB) (RKB) (ftKB) (ftKB) Type Date Com GAS LIFT;10,203.1 a 10,610.0 10,650.0 5,126.8 5,149.1 FRAC 3/14/1999 PLACED 93,0008 PROPPANT IN FORMATION \ 10,585.0 10,617.0 5,112.9 5,130.7'FRAC 1/16/2008 PLACED TOTAL OF 186,0008 OF 16/20 CERAMIC N. PROPPANT BEHIND PIPE W/9 PPA ON PERFS Cement Squeezes • \. Top(ND) Earn(TVD) • \ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des 5 Stag Date Com • \ 8,233.0' 10,650.0 4,100.8 5,149.1 Cement Squeeze 12/15/201 ALL PERFS CEMENTED DURING 2015 RWO '.'' \ NIPPLE;10,254.8 ,3',: - 41\ 7,967.7 10,650.0 4,013.3 5,149.1-Cement Squeeze 12/15/201 ALL PERFS CEMENTED DURING RWO 2015 5 v Notes:General&Safety • ...•V End Date Annotation \• 7/17/2009 NOTE:View Schematic w/Alaska Schematic9.0 LOCATOR;10,262.0 �Y SEAL ASSY;10,263.5 ',E.: \: .La\, no, '.i N. 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III 1 .... 110 lc-- . ' ,- - CY) > O. ° 0 –"•••••"1",.........-"IIIIN1111110k.„----- , - - Trift, , _. _ ......„ . ', • C)- 0 -6 `-1 4-, _ 4— . 2r ›N 0 ...0 C 4..1 . • CO >'' (/) ,•. ..........- %. _...... .. i u o 0 , • Q) 0._ a) (f) , i i 1 • • (/). , _c 0 a cu NO Ille i . . • o") c) s....., ci.) 1111/11111, cs A I ....r Mr/ - CO Ar/ . 0 . cNi '4—',_ L_ - • „. • -- -,1,41-----., i /'-lrrrr,ntiipr.til •— >N N11,41 I liPt1 IliV.,..,:rklifiriii.„ -: : ---- e4tst,Wartemo .''.1,--',.' '''''''•"''''''''''''''- . ...." (..) CI < \ ., FiEchi VtV 0 0 JAN 1. 0 20' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ,nrcc WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil , Gas SPLUG ❑ Other ❑ Abandoned ❑ Suspended0, 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development 0 • Exploratory ❑ GINJ ❑ WINJ❑ WAG❑ WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp. Susp. or ,/ 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 2/18/2015 e 199-001 / 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 1/25/1999 50-103-20287-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 58'FNL,748'FEL, Sec. 3,T9N, R7E, UM 2/8/1999 KRU TARN 2N-320 Top of Productive Interval: 9. Ref Elevations: KB: aft e.L 17. Field/Pool(s): 2122'FSL, 1808'FWL, Sec. 33,T1ON, R7E, UM GL: 120.'1`` BF: 111'¢ Kuparuk River Field/Tarn Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 2255'FSL, 1238'FWL, Sec. 33,T1ON, R7E, UM ADL 380054 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 460845 y- 5911950 Zone- 4 11061/5384 4602 TPI: x- 452850 y- 5914175 Zone- 4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 452281 y- 5914312 Zone- 4 n/a 1227/1210 5. Directional or Inclination Survey: Yes ❑ (attached) No 0 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 n/a (ft MSL) n/a 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter,formation tester,temperature, cement evaluation, casing collar locator,jewelry, and perforation record. Acronyms may be used.Attach a separate page if necessary none SCANNED JUN 0 0 2016 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 16 62.5 H-40 Surface 110 Surface 110 24 9 cu yds Oregon Portland Type III 7.625 29.7 L-80 Surface 3253 Surface 2310 9.875 394 sx AS III L&251 sx Class G 5.5 15.5 L-80 Surface 10256 Surface 4932 6.75 248 sx Class G 3.5 9.3 L-80 10256 11040 4932 5372 6.75 included above 24.Open to production or injection? Yes ❑ No 0 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3 1/2 7946 perfs cemented off 26.ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes❑ No 0 Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 7967-8283, 80.6 bbls of 15.8 ppg Class G Cement w/15.8 8283-10650 Ib/bbls of cement 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift,etc.): Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period ..+ Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate �► /// Form 10-407 Revised 11/2015 1/7-7- 519 //6, CONTINU D QIN PAGE 2 RBDMS1. JAN 2 5 2016 Submit ORIGINIAL only/6 i • 28.CORE DATA Conventional Core(s): Yes ❑ No E Sidewall Cores: Yes ❑ No 0 If Yes, list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions, core chips, photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 0 Permafrost-Top Surface Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1227 1210 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 10330 4973 information, including reports, per 20 AAC 25.071. C80 3652 2460 Camp_SST 3/62 25uu C50 7045 3699 C40 7526 3867 C37 8037 4036 T6 9731 4676 T4 10222 4914 T3 10330 4973 Top_Berm 10384 5002 T2 10704 5180 Base_Berm 10709 5182 K3 10726 5192 TD 11061 5384 Formation at total depth: K3 31. List of Attachments: Summary of Daily Operations, Schematic Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, oaleontoloaical report,production or well test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. 1-14-110 Contact: Jonathan Coberly A 265-1013 Email: Jonathan.CoberlyAconocophillips.com Printed Name: J.B. Packer'J� Title: Supervising Workover Engineerq Signature: 'r � Phone: 265-8545 Date: // / ( (/�6 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la: 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 1b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection, Salt Water Disposal,Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing,Ground Level,and Base Flange 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 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). perfs cemen Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: 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 27: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump, Submersible,Water Injection, Gas Injection, Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Pursuant to 20 AAC 25.071,submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram, summary of daily well operations,directional or inclination survey,and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only • 0 ,.0 x Operations Summary (with Timelog Depths) 2N-320 aCot oco ftlips Rig: NABORS 9ES Job: RECOMPLETION Time Log Start.Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (WKS); End Depth(ftKB) 12/1/2015 12/1/2015 4.00 MIRU MOVE RURD P RD the rig floor. Bridal up the blocks 0.0 0.0 06:00 10:00 and lower the cattle chute. Pay out the tugger,man rider,and bridal lines. Remove A-leg pins. 12/1/2015 12/1/2015 2.00 MIRU MOVE RURD P Lower the derrick. RD all berming 0.0 0.0 10:00 12:00 from around the rig. Remove cutting box. 12/1/2015 12/1/2015 2.00 MIRU MOVE MOB P Pull the pits away from the sub and 0.0 0.0 12:00 14:00 install the jeep. 12/1/2015 12/1/2015 0.50 MIRU MOVE RURD P Pick up herculite and pit rig mats. 0.0 0.0 14:00 14:30 Raise the back cellar door. 12/1/2015 12/1/2015 1.00 MIRU MOVE MOB P Jack up the sub,move the sub off well 0.0 0.0 14:30 15:30 1F-09. 12/1/2015 12/1/2015 1.00 MIRU MOVE RURD P Pick up herculite and rig mats from 0.0 0.0 15:30 16:30 around the 1F-09. Clean up around the well. 12/1/2015 12/1/2015 0.50 MIRU MOVE MOB P Move the sub to 1F pad entrance. 0.0 0.0 16:30 17:00 12/1/2015 12/1/2015 6.75 MIRU MOVE MOB P Move the sub 2.3 miles from 1F pad 0.0 0.0 17:00 23:45 entrance down 1F access road to the spine road. Turn left onto the spine road and move the sub 2.9 miles to the Oliktok Y. 12/1/2015 12/2/2015 0.25 MIRU MOVE WAIT P Allow traffic to get around the sub. 0.0 0.0 23:45 00:00 12/2/2015 12/2/2015 3.50 MIRU MOVE MOB P Move the sub 6.9 miles from the 0.0 0.0 00:00 03:30 Oliktok Y to 2B pad. 12/2/2015 12/2/2015 5.50 MIRU MOVE WAIT P Wait for field crew change. 0.0 0.0 03:30 09:00 12/2/2015 12/2/2015 13.50 MIRU MOVE MOB P Move the sub14.6 miles from 2B pad 0.0 0.0 09:00 22:30 to 2N pad and stag on the edge of the pad. 12/2/2015 12/3/2015 1.50 MIRU MOVE RURD P Prep around well 2N-320 to set rig 0.0 0.0 22:30 00:00 mats. 12/3/2015 12/3/2015 1.00 MIRU MOVE RURD P Continue to prep around well 2N-320 0.0 0.0 00:00 01:00 to set rig mats. SimOps: Move the pits,mechanic shop,welding shop,electrical shop, and satellite office 27 miles from 1F pad to 2N pad. 12/3/2015 12/3/2015 1.50 MIRU MOVE RURD P PJSM. Raise the derrick and pin the 0.0 0.0 01:00 02:30 A-legs. Hang the tree in the cellar. 12/3/2015 12/3/2015 2.50 MIRU MOVE RURD P Spool and inspect tugger and man 0.0 0.0 02:30 05:00 rider lines. Raise and pin the cattle chute. Set rig mats around well 2N- 320. 12/3/2015 12/3/2015 1.00 MIRU MOVE RURD P Lay out herculite around well 2N-320 0.0 0.0 05:00 06:00 and place the tubing head adaptor behind the well. 12/3/2015 12/3/2015 2.50 MIRU MOVE MOB P Spot the sub over well 2N-320. Close 0.0 0.0 06:00 08:30 the cellar door and insulate. 12/3/2015 12/3/2015 1.00 MIRU MOVE RURD P Take the jeep off the pits and lay out 0.0 0.0 08:30 09:30 herculite for the pits. 12/3/2015 12/3/2015 2.50 MIRU MOVE MOB P Spot the pit to the sub. 0.0 0.0 09:30 12:00 Page 1/17 Report Printed: 1/15/2016 . i Operations Summary (with Timelog Depths) 2N-320 ConocoPhillips Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X ; Operation tftKB) End Depth(ftKD); 12/3/2015 12/3/2015 4.50 MIRU MOVE RURD P RU berming around the cellar and pits. 0.0 0.0 12:00 16:30 Spot LEPD tank and cuttings box. RU berming around LEPD tank and cuttings box. Put mud pump#1  back together. Accept Nabors 9ES at 16:30 hours on 12-3-15 12/3/2015 12/3/2015 4.50 MIRU WELCTL RURD P Start loading the pits with 11.2 ppg 0.0 0.0 16:30 21:00 brine. Bridal down,pin the blocks to the TD,pin the torque tube,and hang the bridal lines. RU Kelly hose and hydraulic service loop to the TD. 12/3/2015 12/3/2015 2.00 MIRU WELCTL MPSP P RU lubricator,open SSV,PT lubricator 0.0 0.0 21:00 23:00 to 2500 psi(good test),and lubricate out 3"'H'BPV. Initial well pressures: Tubing=2000 psi, IA=2800 psi,and OA= 160. RD lubricator and close SSV due to leaking master valve on the tree. 12/3/2015 12/4/2015 1.00 MIRU WELCTL RURD P RU circulating lines to the IA and the 0.0 0.0 23:00 00:00 tubing for the well kill operation. Open the SSV on the tree. 12/4/2015 12/4/2015 0.50 MIRU WELCTL SEQP P PJSM. PT all surface lines to 3000 psi 0.0 0.0 00:00 00:30 (good test). 12/4/2015 12/4/2015 3.00 MIRU WELCTL KLWL P SITP=2000 psi and SICP=2800 psi. 0.0 0.0 00:30 03:30 Open the IA and bleed off the gas; recovered 8 bbls to the kill tank. SITP = 1580 psi and SICP=1700 psi. Reverse circulate 11.2 ppg brine down the IA taking returns up the tubing to the kill tank at 2 BPM. Pumped 73 bbls and shut down to strap the kill tank. Kill tank had 159 bbls of foamed up,gas cut,paraffin returns. After 15 minutes the foam subsided and there was 93 bbls in the kill tank. 12/4/2015 12/4/2015 0.50 MIRU WELCTL OWFF P Monitor the well pressure SITP 0.0 0.0 03:30 04:00 pressure increased from 410 psi to 780 psi. 12/4/2015 12/4/2015 1.75 MIRU WELCTL KLWL P Continue to reverse circulate 11.2 ppg 0.0 0.0 04:00 05:45 brine down the IA taking returns up the tubing to the kill tank at 2 BPM while holding 1500 psi back pressure. Pumped 203 bbls and returned 97 bbls to the kill tank. Shut in the well. 12/4/2015 12/4/2015 0.25 MIRU WELCTL OWFF T Monitor the well pressure: SITP=940 0.0 0.0 05:45 06:00 psi and SICP=200 psi. Open the IA and tubing to bleed off the gas and the pressure did not bleed down quickly. SITP=850 psi and SICP=800 psi. 12/4/2015 12/4/2015 2.50 MIRU WELCTL KLWL T Circulate 140 bbls down the tubing 0.0 0.0 06:00 08:30 taking returns up the IA to the kill tank at 3 BPM= 117 psi. XX bbls returned to the kill tank;lost XX bbls to the formation. 12/4/2015 12/4/2015 0.50 MIRU WELCTL KLWL T Line up to circulate through the rig 0.0 0.0 08:30 09:00 choke manifold to the pits. Pump 38 bbls at 3 BPM=190 psi with no returns. Page 2/17 Report Printed: 1/15/2016 • 1110 Operations Summary (with Timelog Depths) 0 2N-320 ocoPhillips Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr), Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/4/2015 12/4/2015 1.50 MIRU WELCTL KLWL T Line up to reverse circulate. Reverse 0.0 0.0 09:00 10:30 circulate 37 bbls down the IA taking returns up the tubing to the pits. No returns at surface. Shut in the well. 12/4/2015 12/4/2015 0.50 MIRU WELCTL OWFF T Monitor the well pressure: Initial- 0.0 0.0 10:30 11:00 SITP=50 psi and SICP=200 psi; Final-SITP=53 psi and SICP=630 psi. 12/4/2015 12/4/2015 0.75 MIRU WELCTL KLWL T Line up to circulate down the tubing. 0.0 0.0 11:00 11:45 Circulate 45 bbls down the tubing taking returns up the IA through the rig choke to the pits with no returns. 12/4/2015 12/4/2015 0.50 MIRU WELCTL OWFF T Monitor the well pressure: Initial- 0.0 0.0 11:45 12:15 SITP=0 psi and SICP=350 psi; Final -SITP=75 psi and SICP=425 psi. 12/4/2015 12/4/2015 1.50 MIRU WELCTL WAIT T Wait for additional 11.2 ppg brine to 0.0 0.0 12:15 13:45 arrive. Load the pits with 11.2 ppg brine. 12/4/2015 12/4/2015 2.25 MIRU WELCTL KLWL T SITP= 125 psi and SICP=450 psi. 0.0 0.0 13:45 16:00 Reverse circulate 80 bbls down the IA taking returns up the tubing to the pits. No returns at surface. Place the tubing and IA in communication, monitor for 15 minutes,and gas is migrating to surface. Shut in the well. 12/4/2015 12/4/2015 1.00 MIRU WELCTL KLWL T Line up to bullhead down the tubing 0.0 0.0 16:00 17:00 and IA. Bullhead 250 bbls of 11.2 ppg brine down the tubing and IA at 4 BPM =340 psi. Shut in the well. 12/4/2015 12/4/2015 1.00 MIRU WELCTL OWFF T With the tubing and IA in 0.0 0.0 17:00 18:00 communication SITP=230 psi and SICP=450 psi. Isolate the tubing from the IA SITP=230 psi and SICP =200 psi. 12/4/2015 12/4/2015 5.00 MIRU WELCTL WAIT T Wait for new KWF 12.2 ppg brine to 0.0 0.0 18:00 23:00 arrive. SimOps: Clean and inspect rig equipment. 12/4/2015 12/5/2015 1.00 MIRU WELCTL RURD T Load the pits with 555 bbls 12.2 ppg 0.0 0.0 23:00 00:00 brine. 12/5/2015 12/5/2015 3.00 MIRU WELCTL RURD T Continue to load the pits with 555 bbls 0.0 0.0 00:00 03:00 12.2 ppg brine. 12/5/2015 12/5/2015 1.75 MIRU WELCTL KLWL T Bullhead 122 bbls of 12.2 ppg brine 0.0 0.0 03:00 04:45 down the IA at 3 BPM(ICP=494 psi and FCP=462 psi). Line up to the tubing and bullhead 92 bbls down the tubing at 3 BPM(ICP=246 psi and FCP=103 psi). Shut in the well. 12/5/2015 12/5/2015 3.75 MIRU WELCTL OWFF T Monitor the well pressures. Initial: 0.0 0.0 04:45 08:30 SITP=0 psi and SICP=50 psi. Final: SITP=220 psi and SICP=450 psi. 12/5/2015 12/5/2015 0.50 MIRU WELCTL KLWL T Bleed 200 psi off the IA through the 0.0 0.0 08:30 09:00 super choke. Bullhead 10 bbls of 12.2 ppg brine down the IA at 1 BPM(ICP =274 psi and FCP=147 psi). Shut in the well. Page 3/17 Report Printed: 1/15/2016 i 0 0 ,,,,, , .,, , Operations Summary (with Timelog Depths) 2N-320 ConooaPhillips Rig: NABORS 9ES 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) 12/5/2015 12/5/2015 2.00 MIRU WELCTL OWFF T Monitor the well pressures;recording 0.0 0.0 09:00 11:00 pressures every 10 minutes. Initial: SITP=230 psi and SICP=110 psi. Final: SITP=240 psi and SICP=310 psi. 12/5/2015 12/5/2015 0.50 MIRU WELCTL KLWL T Bleed 100 psi off the IA through the 0.0 0.0 11:00 11:30 super choke. Bullhead 10 bbls of 12.2 ppg brine down the IA at 1 BPM(ICP =138 psi and FCP=55 psi). Shut in the well. 12/5/2015 12/5/2015 2.00 MIRU WELCTL OWFF T Monitor the well pressures;recording 0.0 0.0 11:30 13:30 pressures every 10 minutes. Initial: SITP=225 psi and SICP=15 psi. Final: SITP=250 psi and SICP=225 psi. 12/5/2015 12/5/2015 0.50 MIRU WELCTL KLWL T Bleed 200 psi off the IA through the 0.0 0.0 13:30 14:00 super choke. Bullhead 10 bbls of 12.2 ppg brine down the IA at 1 BPM(ICP =47 psi and FCP=45 psi). Shut in the well. 12/5/2015 12/5/2015 1.00 MIRU WELCTL OWFF T Monitor the well pressures;recording 0.0 0.0 14:00 15:00 pressures every 10 minutes. Initial: SITP=250psi and SICP=0 psi. Final: SITP=250 psi and SICP=0 psi. 12/5/2015 12/5/2015 0.50 MIRU WELCTL KLWL T Bleed 175 psi off the tubing through 0.0 0.0 15:00 15:30 the super choke. Bullhead 10 bbls of 12.2 ppg brine down the tubing at 1 BPM(ICP=96 psi and FCP=53 psi). Shut in the well. 12/5/2015 12/5/2015 2.00 MIRU WELCTL OWFF T Monitor the well pressures;recording 0.0 0.0 15:30 17:30 pressures every 10 minutes. Initial: SITP=10 psi and SICP=90 psi. Final: SITP=100 psi and SICP=200 psi. DHD fluid level shot at 16:00 hours: Tubing=498'and IA=906'. DHD fluid level shot at 17:00 hours: Tubing=918'and IA=1038'. 12/5/2015 12/5/2015 1.00 MIRU WELCTL KLWL T Bleed 100 psi off the tubing and IA 0.0 0.0 17:30 18:30 through the super choke at the same time. SITP=100 and SICP 70 psi. DHD fluid level shot at 17:00 hours: Tubing=918'and IA=804'. 12/5/2015 12/5/2015 0.50 MIRU WELCTL OWFF T Bullhead 10 bbls of 12.2 ppg brine 0.0 0.0 18:30 19:00 down the tubing at 1 BPM(ICP= 110 psi and FCP=53 psi). Bullhead 10 bbls of 12.2 ppg brine down the IA at 1 BPM(ICP=130 psi and FCP=46 psi).Shut in the well. 12/5/2015 12/5/2015 1.75 MIRU WELCTL OWFF T Monitor the well pressures;recording 0.0 0.0 19:00 20:45 pressures every 10 minutes.SITP= 50 and SICP 50 psi. Final: SITP= 100 psi and SICP=175 psi. 12/5/2015 12/5/2015 1.00 MIRU WELCTL KLWL T Bleed 100 psi off the IA and bleed 45 0.0 0.0 20:45 21:45 psi off the tubing through the super choke. SITP=20 and SICP 75 psi. Bullhead 10 bbls of 12.2 ppg brine down the tubing at 1 BPM(ICP= 126 psi and FCP=60 psi). Bullhead 23 bbls 12.2 ppg brine down the IA at 1 BPM(ICP=54 psi and FCP=50 psi). Page 4/17 Report Printed: 1/15/2016 ,;,..!, 0 • 01 Operations Summary (with Timelog Depths) 2N-320 C_onocoPhitiips Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/5/2015 12/6/2015 2.25 MIRU WELCTL OWFF T Monitor the well pressures;recording 0.0 0.0 21:45 00:00 pressures every 10 minutes.SITP=0 and SICP 38 psi. Final: SITP=100 psi and SICP= 110 psi. 12/6/2015 12/6/2015 1.25 MIRU WELCTL KLWL T Bleed 185 psi off the IA and bullhead 0.0 0.0 00:00 01:15 10 bbls of 12.2 ppg brine down the tubing at 1 BPM(ICP=48 psi and FCP=46 psi). Bleed 20 psi off the tubing through the super choke and bullhead 10 bbls 12.2 ppg brine down the IA at 1 BPM(ICP=44 psi and FCP=42 psi). 12/6/2015 12/6/2015 2.25 MIRU WELCTL OWFF T Monitor the well pressures;recording 0.0 0.0 01:15 03:30 pressures every 10 minutes.SITP=5 and SICP 5 psi. Final: SITP=5 psi and SICP=130 psi. 12/6/2015 12/6/2015 0.50 MIRU WELCTL KLWL T Bleed 115 psi off the IA and bullhead 0.0 0.0 03:30 04:00 10 bbls of 12.2 ppg brine down the tubing at 1 BPM(ICP=26 psi and FCP=8 psi). 12/6/2015 12/6/2015 2.75 MIRU WELCTL OWFF T Monitor the well pressures;recording 0.0 0.0 04:00 06:45 pressures every 10 minutes.SITP= 10 and SICP 0 psi. Final: SITP=12 psi and SICP= 149 psi. 12/6/2015 12/6/2015 1.00 MIRU WELCTL KLWL T Bleed the IA to 10 psi. Place the 0.0 0.0' 06:45 07:45 tubing and IA in communication SIP= 12 psi. Bleed the pressure on the IA to 9 psi and tubing to 4 psi. 12/6/2015 12/6/2015 5.75 MIRU WELCTL OWFF T Monitor the well pressures;recording 0.0 0.0 07:45 13:30 pressures every 10 minutes.SITP=4 and SICP 9 psi. Final: SITP=12 psi and SICP=205 psi. SimOps: Build 60 bbls 300 visc pill and visc up pit#2 to 80 visc. 12/6/2015 12/6/2015 1.25 MIRU WELCTL KLWL T Bleed 185 psi off the IA and bullhead 0.0 0.0 13:30 14:45 40 bbls 300 visc pill followed by 120 bbls of 80 visc 12.2 ppg brine at 6 BMP=2480 psi. 12/6/2015 12/6/2015 1.75 MIRU WELCTL OWFF T Monitor the well pressures;recording 0.0 0.0 14:45 16:30 pressures every 10 minutes.SITP= 22 and SICP 18 psi. Final: SITP=72 psi and SICP=10 psi. DHD fluid level shot at 16:00 hours: Tubing=822' and IA=468'. 12/6/2015 12/6/2015 1.50 MIRU WELCTL KLWL T Place the tubing and IA in 0.0 0.0 16:30 18:00 communication. and bleed off the pressure through the super choke. SITP=12 psi and SICP=5 psi. DHD fluid level shot at 17:00 hours: Tubing =852'and IA=594'. 12/6/2015 12/6/2015 1.00 MIRU WELCTL OWFF T Monitor the well pressures;recording 0.0 0.0 18:00 19:00 pressures every 10 minutes.SITP= 20 and SICP 5 psi. Final: SITP=20 psi and SICP=5 psi. 12/6/2015 12/6/2015 1.25 MIRU WELCTL COND T Pit#2 visc went up to 220 visc and 0.0 0.0 19:00 20:15 thin back to 80 visc. Page 5/17 Report Printed: 1/15/2016 I Operations Summary (with Timelog Depths) 4 2N-320 ConocoPhillips Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/6/2015 12/6/2015 0.75 MIRU WELCTL KLWL T Bleed the tubing to 0 psi through the 0.0 0.0 20:15 21:00 super choke. Pump 20 bbls of 220 visc pill at 2 BPM and chase with 64 bbls of 80 vise 12.2 ppg brine at 5 BPM=330 psi. Bleed the IA to 2.5 psi. 12/6/2015 12/7/2015 3.00 MIRU WELCTL OWFF T Monitor the well pressures;recording 0.0 0.0 21:00 00:00 pressures every 10 minutes.SITP= Vac and SICP 2.5 psi. Final: SITP= Vac psi and SICP=2 psi. SimOps: Load the pits with 146 bbls 12.2 ppg brine and vise up to 80 vise. 12/7/2015 12/7/2015 1.00 MIRU WELCTL KLWL T Pump 20 bbls 220 vise pill at 2 BPM 0.0 0.0 00:00 01:00 followed by 99 bbls 80 vise 12.2 ppg brine at 4 BPM. 12/7/2015 12/7/2015 1.50 MIRU WELCTL OWFF T Monitor the well pressures;recording 0.0 0.0 01:00 02:30 pressures every 10 minutes.SITP= Vac and SICP Vac psi. Final: SITP= Vac psi and SICP=Vac psi. Both the tubing and IA are on a vac which was verified in the cellar by opening both up to the atmosphere. 12/7/2015 12/7/2015 1.00 MIRU WELCTL RURD P PJSM. Blow down circulating line and 0.0 0.0 02:30 03:30 choke manifold. RD circulating equipment in the cellar. 12/7/2015 12/7/2015 0.50 MIRU WHDBOP MPSP P Install 3"'H'BPV with dry rod. 0.0 0.0 03:30 04:00 12/7/2015 12/7/2015 2.00 MIRU WHDBOP NUND P PJSM. Bleed off the tubing hanger 0.0 0.0 04:00 06:00 void,ND the tree,pull the tree free with the TD,ND tubing head adapter, and install the blanking plug. 12/7/2015 12/7/2015 2.50 MIRU WHDBOP NUND P NU the DSA and NU the BOP stack. 0.0 0.0 06:00 08:30 Install the mouse hole,install the riser, air up the boot,and install turnbuckles. 12/7/2015 12/7/2015 3.00 MIRU WHDBOP RURD P Fill the choke manifold and BOPE 0.0 0.0 08:30 11:30 stack with fresh water. Grease the choke valves,manual choke,manual kill,HCR choke,HCR kill,and test spool valves. Energize the Koomey unit. MU the 3-1/2"test joint to the blanking plug and MU 3-1/2"EUE TIW. Page 6/17 Report Printed: 1/15/2016 r ! Operations Summary (with Timelog Depths) . 2N-320 CscoPhillips Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time: End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 12/7/2015 12/7/2015 4.50 MIRU WHDBOP BOPE P Conduct initial BOPE test to 250/2500 0.0 0.0 11:30 16:00 psi: test 2-7/8"x 5"VBR's(upper pipe rams and lower pipe rams)with 3-1/2" test joint;test annular to 250/2500 with 3-1/2"test joints;conducted CPAI Koomey drawdown test(all tested passed). The states right to witness was waived by AOGCC inspector Louis Grimaldi via email on 12/3/15 at 11:13 hours. Tests: 1) Annular with 3-1/2"test joint,3-1/2" EUE 8rd TIW,4"Dart Valve,Kill Demco,Chokes 1,2,3,&16(Passed) 2) Upper Pipe Rams with 3-1/2"test joint,4"HT-40 TIW, HCR Kill Chokes 4,5,&6(Passed) 3)Lower Pipe Rams with 3-1/2"test joint,4"HT-40 TIW(Passed). 4) Blind Rams,Manual Kill,Chokes 7, 8,&9(Passed) 5) Bean,Super Choke,HCR Kill (Passed) 6) Upper IBOP(hydraulic),Chokes 10 &11 (Passed) 7) Lower IBOP(manual),Chokes 12, 13,&14(Passed) 8) Choke 15(Passed) 9) HCR Choke(Passed) 10)Manual Choke(Passed) 11)Blinds,HCR Kill,Outer Test Spool (Passed) 12)Blinds,HCR Kill,Inner Test Spool (Passed) Conduct CPAI Koomey Draw Down Test: Starting Accumulator Pressure=2950 psi Accumulator Pressure After Closer= 1700 psi Pressure Gain of 200 psi=35 seconds Full System=154 Seconds Average N2(6 Bottles)=1988 psi 12/7/2015 12/7/2015 1.00 MIRU WHDBOP RURD P Blow down the test pump lines,choke 0.0 0.0 16:00 17:00 manifold,HCR choke,HCR kill, Pull blanking plug with test joint. Lay down the test joint and RD BOPE testing equipment. 12/7/2015 12/7/2015 0.50 MIRU WHDBOP MPSP P Pull 3"'H'BPV with dry rod. 0.0 0.0 17:00 17:30 12/7/2015 12/7/2015 1.50 COMPZN RPCOMP PULL P RU 4"DP elevators,PU landing joint, 10,280.0 10,250.0 17:30 19:00 MU landing joint to the tubing hanger, MU 3-1/2"TIW,MU crossover,and MU TD. BOLDS,unseat tubing hanger,pull seal assembly free at 165K,and pull tubing hanger to the rig floor(PU=100K and SO=62K). Page 7/17 Report Printed: 1/15/2016 • • Operations Summary (with Timelog Depths) 2N-320 Cif Rig: NABORS 9ES 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 MKS) 12/7/2015 12/7/2015 1.00 COMPZN RPCOMP RURD P Bring Weatherford power tubing tong 10,250.0 10,250.0 19:00 20:00 to the rig floor and thaw them out. RD 4"DP elevators and RU 3-1/2"tubing elevators. Fill the IA with 12 bbls of brine. 12/7/2015 12/7/2015 0.50 COMPZN RPCOMP PULL P Lay down the tubing hanger,break out 10,250.0 10,250.0 20:00 20:30 crossover,break out 3-1/2"EUE 8rd TIW,and lay down landing joint. Fill the tubing with 20 bbls of brine. 12/7/2015 12/8/2015 3.50 COMPZN RPCOMP PULL P POOH laying down 3-1/2"tubing 10,250.0 8,530.0 20:30 00:00 removing jewelry from 10250'to 8530' RKB(PU=83K and SO=51K). Strap,tally,and removing tubing from pipe shed. Filling the tubing and IA every 15 joints with double pipe displacement. 12/8/2015 12/8/2015 13.50 COMPZN RPCOMP PULL P Continue POOH laying down 3-1/2" 8,530.0 461.0 00:00 13:30 tubing removing jewelry from 8530'to surface. Strap,tally,and removing tubing from pipe shed. Filling the tubing and IA every 15 joints with double pipe displacement. Recovered 313 joints of the original 326 jts ran. Pin pulled from cplg on jt# 315. leaving 13 jts in the hole along with Misc jewelry. Estimated TOF= 9,815-ft and no slick line tools were recovered. Left to recover is: 461-ft of 3-1/2 completion 37-ft of slick line tools 12/8/2015 12/8/2015 3.00 COMPZN RPCOMP WAIT T Clean and Clear rig floor,install wear 461.0 13:30 16:30 ring 9-1/16"ID x 10-3/4"OD x.98-ft while waiting for fishing equipment to arrive 12/8/2015 12/8/2015 0.50 COMPZN RPCOMP SVRG P Service top drive while waiting for 16:30 17:00 fishing equipment to arrive 12/8/2015 12/9/2015 7.00 COMPZN RPCOMP WAIT T Discussed with town engineer about 17:00 00:00 lowering the KWF from 12.0 ppg to 11.8 ppg. The KWF was already lowered from the original 12.2 ppg to the 12.0 ppg on 12-7-15. The approval was given and the surface volumes were conditioned from 12.0 to 11.8 ppg with a 70 vise. While continuing to Top Fill the hole with 20 bph of Non viscosified 12.0 ppg NaBr during the loading of the work string and Fishing BHA#1. 12/9/2015 12/9/2015 3.00 COMPZN RPCOMP WAIT T Continue to prep for RIH w/fishing 00:00 03:00 BHA 12/9/2015 12/9/2015 1.25 COMPZN RPCOMP BHAH P PJSM,PU,MU and Fishing BHA#1 0.0 190.0 03:00 04:15 (spear)and RIH to 190-ft 12/9/2015 12/9/2015 12.75 COMPZN RPCOMP TRIP P Continue to RIH with BHA#1 PU 3-1/2 190.0 9,817.0 04:15 17:00 PH-6 Work string from 190-ft to 9,817- ft 135k up wt 60k do wt. 12/9/2015 12/9/2015 0.50 COMPZN RPCOMP FISH P PU,MU and RIH w/working jt and tag 9,817.0 9,832.0 17:00 17:30 12-ft in on jt#309. at 9,832-ft w/ ORKB correction. Engage fish and relax jars,lost bite,unable to re engage. Page 8/17 Report Printed: 1/15/2016 • • Operations Summary (with Timelog Depths) 2N-320 ConocoPhiiliips Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr), Phase Op Code Activity Code Time P-T-X Operation (ftki End Depth(ftKB) 12/9/2015 12/9/2015 1.50 COMPZN RPCOMP CIRC P Displace 12.0 ppg KWF with 11.8 ppg 9,832.0 9,832.0 17:30 19:00 KWF while pumping 2 bpm at 250 psi. establish SPR with pump#1 2 bpm @ 400 psi/3.5 bpm @ 930 psi Pump#2 2 bpm @ 740 psi/3.5 bpm @ 2,060 psi with up and dn weights of 135k up wt, 60k dn wt. 12/9/2015 12/9/2015 1.00 COMPZN RPCOMP OWFF P Monitor well for flow,break down X- 9,832.0 9,832.0 19:00 20:00 O's on jt#309. Lay joint out of string and plan to pull 79 std's,PU jt#330 to replace Jt#72 that was damaged during PU. Estimated fluid losses per hr=45 bph 12/9/2015 12/10/2015 4.00 COMPZN RPCOMP TRIP P POOH racking back 3-1/2, 12.75#,P- 9,832.0 3,230.0 20:00 00:00 110 PH-6 work string from 9,832-ft.to 3,230-ft. Double displacing every 5 std's. 12/10/2015 12/10/2015 2.00 COMPZN RPCOMP TRIP P Continue to POOH racking back 3-1/2, 3,230.0 190.0 00:00 02:00 12.75#,P-110 PH-6 work string from 3,230-ft.to 190-ft Double displacing every 5 std's. 12/10/2015 12/10/2015 1.00 COMPZN RPCOMP BHAH P POOH w/BHA#1 -No fish recovered. 190.0 0.0 02:00 03:00 Signs show grapple not to have fully engaged. 12/10/2015 12/10/2015 1.00 COMPZN RPCOMP BHAH P Add Lubricated Bumper sub to BHA 0.0 198.0 03:00 04:00 and RIH to 198-ft with BHA#2 12/10/2015 12/10/2015 6.00 COMPZN RPCOMP TRIP P RIH w/BHA#2 from 198-ft to 9829-ft 198.0 9,829.0 04:00 10:00 140k up wt,60k dn wt while double displacing(66.7 BBLS)with 11.8 ppg 70 vise KWF. 12/10/2015 12/10/2015 1.00 COMPZN RPCOMP FISH P MU to top drive and attempt to engage 9,829.0 9,829.0 10:00 11:00 TOF @ 9829-ft Pulled 20k OSW and came free-Showed to be grapple slip. BO from Top drive and Blow down. 12/10/2015 12/10/2015 5.00 COMPZN RPCOMP TRIP P POOH from 9829-ft to 198-ft. 9,829.0 198.0 11:00 16:00 12/10/2015 12/10/2015 2.00 COMPZN RPCOMP BHAH P POOH with BHA#2 and found grapple 198.0 0.0 16:00 18:00 in the released position. Clean and clear floor. 12/10/2015 12/10/2015 1.50 COMPZN RPCOMP WAIT T Waiting for fishing tools to arrive from 0.0 0.0 18:00 19:30 Dead Horse. filling hole every hour with 25 bbls of 11.8 ppg KWF 12/10/2015 12/10/2015 2.00 COMPZN RPCOMP BHAH P PJSM,PU,MU and RIH w/Fishing 0.0 201.0 19:30 21:30 BHA#3 to 201-ft. 12/10/2015 12/11/2015 2.50 COMPZN RPCOMP TRIP P RIH from 201-ft to 4,890-ft 84K up wt, 201.0 4,890.0 21:30 00:00 53K dn wt,double displacing 12/11/2015 12/11/2015 2.00 COMPZN RPCOMP TRIP P Continue to RIH f/4,806-ft to 9,204-ft 4,890.0 9,204.0 00:00 02:00 128K up wt,56K Dn wt. Double displacing w/11.8 ppg KWF 12/11/2015 12/11/2015 1.50 COMPZN RPCOMP SLPC P Slip and cut 99-ft of drill line. Inspect 9,204.0 9,204.0 02:00 03:30 and service draw works Page 9/17 Report Printed: 1/15/2016 Operations Summary (with Timelog Depths) ,, 2N-320 ConocoPhim ps , Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKEi) End Depth(ftKE) 12/11/2015 12/11/2015 1.50 COMPZN RPCOMP TRIP P Continue to RIH w/BHA#3 from 9,204.0 9,832.0 03:30 05:00 9,204-ft to 9,767-ft,MU X-O to Top Drive and RIH to TOF @ 9,832-ft. 140K up wt,60K dn wt. 12/11/2015 12/11/2015 2.00 COMPZN RPCOMP FISH P Engage fish at 9,832-ft,slack off to 9,832.0 9,832.0 05:00 07:00 45K(15k dn)on fish and pull to150K (10K osw). Let jars bleed,continue to PU to165K(25K osw)and lost bite. Set back down and re-engage fish pull back to 150K let jars bleed,pull up to 200K.(60K osw), lost bite,slack off to 35K (25K dn)on fish and pull 155K (15K osw)let jars bleed,pull up to 180K(40K osw),wt indicator showed 5K extra, Load well on IA with hole fill -20 bbls to fill. 12/11/2015 12/11/2015 6.25 COMPZN RPCOMP TRIP P POOH from 9,832-ft to 201-ft. While 9,832.0 201.0 07:00 13:15 double displacing every 5 stds. 12/11/2015 12/11/2015 1.00 COMPZN RPCOMP BHAH P POOH with BHA#3-No fish,missing 201.0 0.0 13:15 14:15 hooks on rope spear. 12/11/2015 12/11/2015 4.75 COMPZN RPCOMP WAIT T Discuss options with Town Engr, 0.0 0.0 14:15 19:00 Decide to RIH w/60-ft wash over assembly in attempt to recover tubing. Call out 4 jts of 4-1/2 Wash pipe and handling equipment. Monitor well while waiting for off site equipment to arrive. DHD Shot 2 fluid levels 1 hr apart-1st-510-ft and 2nd-546-ft. 12/11/2015 12/11/2015 3.50 COMPZN RPCOMP BHAH P Load pipe shed with BHA#4 and prep 0.0 255.0 19:00 22:30 for running. Held PJSM. Change out elevators, PU,MU and RIH w/4-3/4" OD x 3-1/2"ID x 4-1/2 WS Hyd Rotary shoe,2-jts of 4-1/2 Wash pipe, Drive sub, Change over elevators and RIH w/ jars,and 2 stands of drill collars,X- O to 255-ft. Change over elevators for 3-1/2 PH-6 Hydril work string. 12/11/2015 12/12/2015 1.50 COMPZN RPCOMP TRIP P RIH w/BHA#4 from 255-ft to 1,941-ft 255.0 1,941.0 22:30 00:00 double displacing every 5 Stds. 53K up wt,48K dn wt. 12/12/2015 12/12/2015 4.50 COMPZN RPCOMP TRIP P Continue to RIH with BHA#4 from 1,941.0 9,818.0 00:00 04:30 1,941-ft to 9,819-ft,lay down stand 103. Page 10/17 Report Printed: 1/15/2016 • Operations Summary (with Timelog Depths) 2N-320 Philllps Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time, End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKS) End Depth(ftKB) 12/12/2015 12/12/2015 4.00 COMPZN RPCOMP MILL P PJSM,MU top drive and wash down 9,818.0 9,833.0 04:30 08:30 to TOF @ 9,833-ft, Obtain parameters: 140K Up wt,65K Dn wt,84K ROT wt. @ 50 rpm's w/4.5K off bottom torque and 6.6K on bottom torque. Circulating @ 1.5 bpm @ 425 psi. SCR at 9,814-ft MP#1 1 bpm at 170 psi,2 bpm @ 270 psi MP#2 1 bpm at 150 psi,2 bpm @ 270 psi KWF @ 11.6 ppg Attempt to mill off 4.5"OD tubing cplg,making no footage-mix lube pill to assist in lower of on bottom torque. 12/12/2015 12/12/2015 1.00 COMPZN RPCOMP CIRC P Load TBG with 20 bbls of safe lube 9,833.0 9,833.0 08:30 09:30 pill. Bull head 50 bbls of safe lube pill followed by 67 bbl neat fluid down IA to spot pill at shoe @ 2 bpm @ 875 psi. 12/12/2015 12/12/2015 5.75 COMPZN RPCOMP MILL P Continue to mill and wash over TBG 9,833.0 9,850.0 09:30 15:15 from 9,833-ft to 9,850-ft. Rotating at 60 rpm's with 4.3K off bottom torque, 6.3K on bottom torque. Circulating @.75 bpm @ 330 psi. 140K Up wt, 65K Dn wt,and 84K ROT wt. 12/12/2015 12/12/2015 0.50 COMPZN RPCOMP SVRG P Grease and service top drive 9,850.0 9,850.0 15:15 15:45 12/12/2015 12/13/2015 8.25 COMPZN RPCOMP MILL P Continue to mill and wash over TBG 9,850.0 9,850.0 15:45 00:00 from 9,833-ft to 9,850-ft. Rotating at 60 rpm's with 4.3K off bottom torque, 6.3K on bottom torque. Circulating @.75 bpm @ 330 psi. 120K Up wt, 65K Dn wt,and 84K ROT wt. 12/13/2015 12/13/2015 4.00 COMPZN RPCOMP MILL P Continue to mill and wash over TBG 9,851.0 9,851.0 00:00 04:00 from 9,850-ft to 9,851-ft. Rotating at 60 rpm's with 4.3K off bottom torque, 6.3K on bottom torque. Circulating @.5 bpm @ 256 psi every 5 minutes to prevent freeze up and fill IA with 3.5 bph 120K Up wt,65K Dn wt,and 84K ROT wt. 12/13/2015 12/13/2015 0.75 COMPZN RPCOMP OWFF P RD blower hose and Blow down Top 9,851.0 9,851.0 04:00 04:45 drive and circulating system while monitoring well for flow. 12/13/2015 12/13/2015 6.25 COMPZN RPCOMP TRIP P POOH from 9,851-ft to 254-ft 120K up 9,851.0 254.0 04:45 11:00 wt,63K do wt. Double displaced with 48.4 bbls 12/13/2015 12/13/2015 2.00 COMPZN RPCOMP BHAH P POOH w/BHA#4 and recovered TBG 254.0 0.0 11:00 13:00 wad in wash pipe. 12/13/2015 12/13/2015 1.00 COMPZN RPCOMP WAIT P Review steps going forward,Decision 0.0 0.0 13:00 14:00 to plug back. RIH w/Retrievable Bridge plug to locate structural integrity for CMT retainer setting depth. 12/13/2015 12/13/2015 4.00 COMPZN RPCOMP BHAH P RIH and break down fishing BHA 0.0 0.0 14:00 18:00 components and off load from rig during delivery of the Retrievable Bridge plug Page 11/17 Report Printed: 1/15/2016 ' � Operations Summary (with Timelog Depths) 1,1;44,;,,,,,,,, 2N-320 ConocoPhillips Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKE) End Depth(ftKE,); 12/13/2015 12/13/2015 1.00 COMPZN PLUG BHAH X Load RBP to rig floor and PU,MU 0.0 48.0 18:00 19:00 same to 48-ft 12/13/2015 12/13/2015 2.25 COMPZN PLUG TRIP X RIH w/BHA#5 from 48-ft to 973-ft, 48.0 973.0 19:00 21:15 Set and shallow test at 2,500 psi for 5 minutes with 50 psi loss.-Blow down top drive. 12/13/2015 12/14/2015 2.75 COMPZN PLUG TRIP X Continue to RIH w/BHA#5 from 973- 973.0 3,137.0 21:15 00:00 ft to 3,137-ft,double displacing every 5 Stds. 65K up wt,47K dn wt 12/14/2015 12/14/2015 0.75 COMPZN PLUG TRIP X Continue to RIH w/BHA#5 from 3,137.0 3,987.0 00:00 00:45 3,137-ft to 3,987-ft,double displacing every 5 Stds. 80K up wt,53K dn wt 12/14/2015 12/14/2015 1.00 COMPZN PLUG CIRC X Circulate surface to surface w/76 bbls 3,987.0 3,987.0 00:45 01:45 at 2.5 bpm @ 475 psi to condition hole volume in preparation for pressure testing casing to 2,500 psi. 12/14/2015 12/14/2015 0.50 COMPZN PLUG PRTS X PT 5-1/2 15.5#L-80 Casing(80% 3,987.0 3,987.0 01:45 02:15 burst=5,600 psi)to 2,500 psi for 5 minutes-Good Test. Blow down. Latch up and release plug. 12/14/2015 12/14/2015 3.25 COMPZN PLUG TRIP X Continue to RIH w/BHA#5 from 3,987.0 8,300.0 02:15 05:30 3,987-ft to 8,301-ft,double displacing every 5 Stds. 110K up wt,54K dn wt 12/14/2015 12/14/2015 0.75 COMPZN PLUG MPSP X Set Model G Lock Set Bridge plug and 05:30 06:15 release off overshot. 12/14/2015 12/14/2015 0.75 COMPZN PLUG RURD X Fill annulus with 10 bbls from hole fill, 8,300.0 8,270.0 06:15 07:00 lay down joint and MU head pin. Close annular. 12/14/2015 12/14/2015 0.75 COMPZN PLUG CIRC X Reverse Circulate 1 TBG volume.of 8,270.0 8,270.0 07:00 07:45 58 bbls at 2 bpm @ 1000 psi to condition hole volume in preparation for pressure testing casing to 2,500 psi. 12/14/2015 12/14/2015 0.25 COMPZN PLUG PRTS X Pressure test 5-1/2 Casing against 8,270.0 8,270.0 07:45 08:00 RBP to 2,500 psi-Good Test. 12/14/2015 12/14/2015 0.25 COMPZN PLUG RURD X RD test equipment and blow down 8,270.0 8,270.0 08:00 08:15 lines 12/14/2015 12/14/2015 0.50 COMPZN PLUG MPSP X Engage and release Bridge plug 8,270.0 8,300.0 08:15 08:45 12/14/2015 12/14/2015 0.50 COMPZN PLUG TRIP X Continue to RIH w/BHA#5 from 8301 8,300.0 8,769.0 08:45 09:15 -ft to 8,769-ft,double displacing every 5 Stds. 120K up wt,54K dn wt 12/14/2015 12/14/2015 0.25 COMPZN PLUG MPSP X Set Model G Lock Set Bridge plug and 8,760.0 8,760.0 09:15 09:30 release off overshot at 8,760-ft 12/14/2015 12/14/2015 0.25 COMPZN PLUG RURD X Lay down joint and MU head pin. 8,760.0 8,760.0 09:30 09:45 Close annular. 12/14/2015 12/14/2015 0.25 COMPZN PLUG PRTS X Pressure test 5-1/2 Casing against 8,760.0 8,760.0 09:45 10:00 RBP to 2,500 psi-Failed Test. Pumping away at 1 bpm at 1,400 psi. 12/14/2015 12/14/2015 0.25 COMPZN PLUG RURD X RD test equipment and blow down 8,760.0 8,760.0 10:00 10:15 lines 12/14/2015 12/14/2015 0.25 COMPZN PLUG MPSP X Engage and release Bridge plug 8,769.0 8,769.0 10:15 10:30 12/14/2015 12/14/2015 0.50 COMPZN PLUG TRIP X POOH w/BHA#5 from 8769-ft to 8,769.0 8,487.0 10:30 11:00 8,487-ft, 120K up wt,54K do wt 12/14/2015 12/14/2015 0.25 COMPZN PLUG MPSP X Set Model G Lock Set Bridge plug and 8,480.0 8,480.0 11:00 11:15 release off overshot at 8,480-ft Page 12/17 Report Printed: 1/15/2016 • S Operations Summary (with Timelog Depths) Ci 2N-320 Conoccehillips Rig: NABORS 9ES 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) 12/14/2015 12/14/2015 0.25 COMPZN PLUG RURD X Lay down joint and MU head pin. 8,480.0 8,450.0 11:15 11:30 Close annular. 12/14/2015 12/14/2015 0.25 COMPZN PLUG PRTS X Pressure test 5-1/2 Casing against 8,450.0 8,450.0 11:30 11:45 RBP to 2,500 psi-Failed Test. Pumping away at 1 bpm at 1,900 psi. 12/14/2015 12/14/2015 0.25 COMPZN PLUG RURD X RD test equipment and blow down 8,450.0 8,450.0 11:45 12:00 lines 12/14/2015 12/14/2015 0.25 COMPZN PLUG MPSP X Engage and release Bridge plug 8,450.0 8,487.0 12:00 12:15 12/14/2015 12/14/2015 0.25 COMPZN PLUG TRIP X POOH w/BHA#5 from 8487-ft to 8,487.0 8,394.0 12:15 12:30 8,394-ft, 120K up wt,54K dn wt 12/14/2015 12/14/2015 0.25 COMPZN PLUG MPSP X Set Model G Lock Set Bridge plug and 8,394.0 8,390.0 12:30 12:45 release off overshot at 8,390-ft 12/14/2015 12/14/2015 0.25 COMPZN PLUG RURD X Lay down joint and MU head pin. 8,390.0 8,360.0 12:45 13:00 Close annular. 12/14/2015 12/14/2015 0.25 COMPZN PLUG PRTS X Pressure test 5-1/2 Casing against 8,360.0 8,360.0 13:00 13:15 RBP to 2,500 psi-Failed Test. 12/14/2015 12/14/2015 0.25 COMPZN PLUG RURD X RD test equipment and blow down 8,360.0 8,360.0 13:15 13:30 lines 12/14/2015 12/14/2015 0.25 COMPZN PLUG MPSP X Engage and release Bridge plug 8,360.0 8,390.0 13:30 13:45 12/14/2015 12/14/2015 0.25 COMPZN PLUG TRIP X POOH w/BHA#5 from 8394-ft to 8,394.0 8,301.0 13:45 14:00 8,301-ft, 118K up wt,54K dn wt 12/14/2015 12/14/2015 0.25 COMPZN PLUG MPSP X Set Model G Lock Set Bridge plug and 8,301.0 8,290.0 14:00 14:15 release off overshot at 8,290-ft 12/14/2015 12/14/2015 0.25 COMPZN PLUG RURD X Lay down joint and MU head pin. 8,290.0 8,260.0 14:15 14:30 Close annular. 12/14/2015 12/14/2015 0.25 COMPZN PLUG PRTS X Pressure test 5-1/2 Casing against 8,260.0 8,260.0 14:30 14:45 RBP to 2,500 psi-Good Test. 12/14/2015 12/14/2015 0.25 COMPZN PLUG RURD X RD test equipment and blow down 8,260.0 8,260.0 14:45 15:00 lines 12/14/2015 12/14/2015 0.25 COMPZN PLUG MPSP X Engage and release Bridge plug 8,260.0 8,290.0 15:00 15:15 12/14/2015 12/14/2015 4.00 COMPZN PLUG TRIP X POOH w/BHA#5 from 8301-ft to 48- 8,301.0 48.0 15:15 19:15 ft, 118K up wt,54K do wt 12/14/2015 12/14/2015 1.00 COMPZN PLUG BHAH X Release retrieving head from 48.0 0.0 19:15 20:15 Retrievable bridge plug. Clean and Clear rig floor. 12/14/2015 12/14/2015 1.25 COMPZN WHDBOP RURD X MU Test plug/wear ring combo 0.0 25.9 20:15 21:30 retrieving tool and retreive wear ring. Install test plug and fill stack. Shell test BOP stack. Page 13/17 Report Printed: 1/15/2016 • • ;2;6;4 6; Operations Summary (with Timelog Depths) 2N-320 ConocaPhillips Rig: NABORS 9ES 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(itK9)` 12/14/2015 12/15/2015 2.50 COMPZN WHDBOP BOPE X Conduct weekly BOP test at 250/ 25.9 21:30 00:00 3,000 psi as per Sundry,testing 2- 7/8"x 5"VBR's(upper pipe rams and lower pipe rams)with 3-1/2"test joint; test annular to 250/3000 with 3-1/2" test joints;conducted CPAI Koomey drawdown test(all tested passed). The states right to witness was waived by AOGCC inspector Bob Noble via Phone on 12/14/15 at 22:00 hours. Note-Phase II road conditions. Tests: 1) Blinds,Kill Demco,Chokes 1,2,3, &16(Passed) 2) Blind Rams, HCR Kill Chokes 4,5, &6(Passed) 3)Blind Rams, Manual Kill,Chokes 7, 8,&9(Passed) 4)Blind Rams,Bean,Super Choke, Manual Kill(Passed) 5) Blind Rams,Chokes 10&11 (Passed) 6)Blind Rams,Chokes 12, 13,&14 (Passed) 12/15/2015 12/15/2015 3.00 COMPZN WHDBOP BOPE X Continue to conduct weekly BOP test 00:00 03:00 at 250/3,000 psi as per Sundry, testing 2-7/8"x 5"VBR's(upper pipe rams and lower pipe rams)with 3-1/2" test joint;test annular to 250/3000 with 3-1/2"test joints;conducted CPAI Koomey drawdown test(all tested passed). The states right to witness was waived by AOGCC inspector Bob Noble via Phone on 12/14/15 at 22:00 hours. Note-Phase II road conditions. Tests: 7)Annular w/3-1/2 Test Joint,Dart, HCR Kill(Passed) 8)Upper VBR's w/3-1/2 Test Joint, HT-40 FOSV, HCR Choke(Passed) 9) Upper VBR's w/3-1/2 Test Joint, Manual Choke,3-1/2 EUE 8rd FOSV (Passed) 10)Lower VBR's,Koomey test 11)Upper VBR's,TD IBOP,Outer Test Spool(Passed) 12)Upper VBR's,TD Lower Manual IBOP, Inner Test Spool(Passed) Conduct CPAI Koomey Draw Down Test: Starting Accumulator Pressure=2950 psi Accumulator Pressure After Closer= 1650 psi Pressure Gain of 200 psi=39 seconds Full System=163 Seconds Average N2(6 Bottles)=2000 psi Page 14/17 Report Printed: 1/15/2016 • • Operations Summary (with Timelog Depths) 2N-320 tip Rig: NABORS 9ES Job: RECOMPLETION Time Log Star Depth Start Time End Time Dur(hr) Phase Op Code Activity CodeTime P-T-X Operation (MKS) End Depth(ftKE), 12/15/2015 12/15/2015 1.75 COMPZN WHDBOP RURD X RD test equipment and Blow down all 03:00 04:45 lines. Re-Install wear ring. 12/15/2015 12/15/2015 1.75 COMPZN PLUG BHAH X PJSM, PU,MU and RIH w/Cement 0.0 42.0 04:45 06:30 retainer,setting tool,X-O,and Handling joint to 42 ft. 12/15/2015 12/15/2015 6.50 COMPZN PLUG TRIP X Trip in hole with retainer on 3-1/2" 42.0 8,295.0 06:30 13:00 12.95#PH-6 workstring from 42'to 8295'. P/U=113k,S/O=56k. 12/15/2015 12/15/2015 0.50 COMPZN PLUG MPSP X Set plug at 8283'(Nabors 9ES RKB) 8,295.0 8,283.0 13:00 13:30 per Baker hand 12/15/2015 12/15/2015 0.50 COMPZN PLUG PRTS X Pressure test IA to 2500 psi for 10 8,283.0 8,283.0 13:30 14:00 minutes.- Good test. Pick up on tubing and verify flow through sleeve. Pressure test tubing to 2500 psi for 10 minutes.-Good test 12/15/2015 12/15/2015 0.50 COMPZN PLUG PULD X Unsting from retainer and lay down 8,283.0 8,253.0 14:00 14:30 single 12/15/2015 12/15/2015 1.00 COMPZN PLUG RURD X Make up FOSV,2-10'pup joints,XO, 8,253.0 8,283.0 14:30 15:30 pump-in sub and cementing hose. RU Cementers-blow air back to truck- verify clear lines. 12/15/2015 12/15/2015 2.50 COMPZN PLUG SQEZ X PJSM,Fill lines with fresh water and 8,283.0 8,280.0 15:30 18:00 PT at 250/3,000 psi. Pump 60 bbls of Fresh water,follow with 20 bbls of Mud push,80.6 bbls of 15.8 ppg Class s G Cement w/15.8 lb/bbl Cemnet, Follow with 10 bbls of Mud push and displace with 47 bbls 11.6 ppg brine,Shut down pumps and un sting from retainer and finish with 3 bbl displacement. 12/15/2015 12/15/2015 1.00 COMPZN PLUG PULD X POOH laying down from 8,280-ft to 8,280.0 7,964.0 18:00 19:00 7,964-ft 12/15/2015 12/15/2015 0.75 COMPZN PLUG CIRC X Reverse circulate surface to surface 7,964.0 7,964.0 19:00 19:45 (188 bbls)at 4.5 bpm @ 2,278 psi. 12/15/2015 12/15/2015 1.00 COMPZN PLUG RURD X RD circulating equipment and pup 7,964.0 7,946.0 19:45 20:45 joints 12/15/2015 12/15/2015 1.25 COMPZN PLUG SLPC X Slip and cut 64-ft of 1.25"Drill line. 7,946.0 7,946.0 20:45 22:00 Service draw works. 12/15/2015 12/16/2015 2.00 COMPZN PLUG PULD X Continue to POOH from 7,946-ft to 7,946.0 6,683.0 22:00 00:00 6,683-ft laying down 3-1/2 PH-6 work string 120k up wt,54k dn wt. 12/16/2015 12/16/2015 2.00 COMPZN PLUG TRIP X RIH from 6,683-ft to 8,078-ft from 6,683.0 8,078.0 00:00 02:00 derrick with 3-1/2 PH-6 work string 120k up wt,54k dn wt. 12/16/2015 12/16/2015 7.50 COMPZN PLUG PULD X Continue to POOH from 8,078-ft 8,078.0 42.0 02:00 09:30 laying down 3-1/2 PH-6 work string to Setting tool BHA 125k up wt,56k dn wt. 12/16/2015 12/16/2015 0.75 COMPZN PLUG BHAH X Lay down BHA and off load Baker 42.0 0.0 09:30 10:15 completion equipment. Clean and clear work area. 12/16/2015 12/16/2015 0.75 COMPZN PLUG PRTS X Close blind rams and pressure up to 0.0 0.0 10:15 11:00 2,500 psi for 30 minutes-Good Test. Page 15/17 Report Printed: 1/15/2016 • • • Operations Summary (with Timelog Depths) 2N-320 ConocoPhillips Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code l Time P-T-X Operation (5K(3)j End Depth(ftKB) 12/16/2015 12/16/2015 12.00 COMPZN PLUG OTHR X Load pipe shed with 275 jts of used 3- 0.0 0.0 11:00 23:00 1/2 kill string from bone yard, inspecting for holes-culled 130 jts. Order out 130 of New from the KCS warehouse. and load 66 jts in shed. Sim ops- Pull wear ring,cleaning pits with Hot water and load BT with Sea water. 12/16/2015 12/17/2015 1.00 COMPZN PLUG PUTB X PJSM,PU,MU and RIH w/TBG cplg 0.0 716.0 23:00 00:00 for WLEG on 23 jts of 3-1/2,9.3#,L- 80,EUE 8rd"USED"tubing to 716-ft 39k Up wt,34k Dn wt. 12/17/2015 12/17/2015 5.50 COMPZN PLUG PUTB X Continue to PU,MU and RIH w/TBG 716.0 3,970.0 00:00 05:30 cplg for WLEG on 23 jts of 3-1/2,9.3#, L-80,EUE 8rd"USED"tubing from 716-ft to 3970' 12/17/2015 12/17/2015 0.50 COMPZN PLUG SVRG X Service rig and top drive. Clean rig 3,970.0 3,970.0 05:30 06:00 floor 12/17/2015 12/17/2015 6.00 COMPZN PLUG PUTB X Continue to P/U,M/U and RIG with 3,970.0 7,967.5 06:00 12:00 used 3-1/2",9.3#, L-80,EUE-8rd tubing from 3970'to 7967'. P/U=95k, S/O=47k, Tagged cement at 7967.65'w/10k. (23.5'in on joint# 256) 12/17/2015 12/17/2015 2.00 COMPZN PLUG CIRC X Establish circulation at 2 bpm @ 1100 7,967.5 7,927.5 12:00 14:00 psi. 12/17/2015 12/17/2015 0.25 COMPZN PLUG RURD X Rig up to reverse circulate 7,927.5 7,925.5 14:00 14:15 12/17/2015 12/17/2015 0.75 COMPZN PLUG CIRC X Reverse circulate 72 bbls. 7,927.5 7,927.5 14:15 15:00 12/17/2015 12/17/2015 0.25 COMPZN PLUG RURD X Rig down reverse circulating 7,927.5 7,927.5 15:00 15:15 equipment. Blow down top drive and lines 12/17/2015 12/17/2015 1.25 COMPZN PLUG THGR X Make up hanger and landing joint. 7,927.5 7,946.0 15:15 16:30 Drain stack. Land hanger with TBG tail at 7,946-ft 95k up wt 47k do wt 12/17/2015 12/17/2015 1.00 COMPZN WHDBOP MPSP P PJSM,Set TWC,and test from below 0.0 0.0 16:30 17:30 to 1,000 psi-blled off and blow down lines. 12/17/2015 12/17/2015 1.50 COMPZN WHDBOP SVRG P PJSM, Flush BOP stack and drain. 0.0 0.0 17:30 19:00 Blow down choke manifold in preparation of BWM. 12/17/2015 12/18/2015 5.00 COMPZN WHDBOP SVRG P PJSM,Perform Between Wells 0.0 0.0 19:00 00:00 Maintenance as per ConocoPhillips procedure. Attempt to pull riser and found heavy gels under table. reset and continue to conduct BWM on UPR's while swapping out with 3-1/2 x 6"VBR's. Open Blind Rams and inspect along with seal,wear plate and measurement. Close up doors. Open and inspect the 2-7/8 x 5"VBR's along with seal,wear plate and measurement. Close uppper doors. 12/18/2015 12/18/2015 3.50 COMPZN WHDBOP SVRG P Continue to finish up Performing 0.0 0.0 00:00 03:30 Between Wells Maintenance as per ConocoPhillips procedure.Close lower doors. Page 16/17 Report Printed: 1/15/2016 • • Operations Summary (with Timelog Depths) • 2N-320 Corroccehillips • Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth MKS); 12/18/2015 12/18/2015 2.50 COMPZN WHDBOP NUND P ND BOPE 0.0 0.0 03:30 06:00 12/18/2015 12/18/2015 3.50 COMPZN WHDBOP NUND P NU tubing head adapter. Make up 0.0 0.0 06:00 09:30 new lower master valve on adapter. Test adapter to 250/5000 psi. Verify tree orientation and nipple up remainder of tree. Note: This is the original Tree, Adapter and TBG Hanger re-Installed w/1-"New"Master Valve 12/18/2015 12/18/2015 0.75 COMPZN WHDBOP PRTS P Fill Xmas tree and pressure test to 0.0 0.0 09:30 10:15 250/5000 psi. Flange leaked. Retightened flange and retested to 250/5000 psi. Good test 12/18/2015 12/18/2015 0.25 COMPZN WHDBOP MPSP P Pull two-way check 0.0 0.0 10:15 10:30 12/18/2015 12/18/2015 1.50 COMPZN WHDBOP CRIH P Rig up to reverse circulate inhibited 0.0 0.0 10:30 12:00 brine. Hold safety meeting 12/18/2015 12/18/2015 1.25 COMPZN WHDBOP CRIH P Inspect line. Reverse circulate 35 bbl 0.0 0.0 12:00 13:15 seawater at 2 bpm, 1300 psi followed by 200 bbl CI seawater at 3 bpm, 1430 psi. 12/18/2015 12/18/2015 0.50 COMPZN WHDBOP CRIH P Rig down reverse circulating 0.0 0.0 13:15 13:45 equipment 12/18/2015 12/18/2015 1.00 COMPZN WHDBOP FRZP P Rig up to freeze protect. Pressure test 0.0 0.0 13:45 14:45 lines to 2500 psi with LRS 12/18/2015 12/18/2015 1.75 COMPZN WHDBOP FRZP P Pump 90 bbl LEPD down IA and put 0.0 0.0 14:45 16:30 IA and tubing in communication,RD LRS 12/18/2015 12/18/2015 0.25 COMPZN WHDBOP MPSP P Dry rod BPV in and set 0.0 0.0 16:30 16:45 12/18/2015 12/18/2015 0.25 COMPZN WHDBOP PRTS P Pressure test BPV in direction of flow. 0.0 0.0 16:45 17:00 12/18/2015 12/18/2015 2.00 DEMOB MOVE RURD P Secure well,clean and clear cellar 0.0 0.0 17:00 19:00 area. Obtain SIPs; Tbg=0,IA=0 and OA=60 Release Nabors 9ES at 19:00 hrs on 12-18-15 Page 17/17 Report Printed: 1/15/2016 KUP D 2N-320 ConocoPhillips if& Well Attribu Max Angle MD TD Alaska Inc. Wellbore API/UWI Field Name Wellbore Status ncl F) MD(ftKB) Act Btm(ftKB) Corlocnt6lipips 501032028700 TARN PARTICIPATING AREA PROD 72.23 7,891.01 11,061.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2N-320,1/15/20169:09:11 AM SSSV.NONE 67 303/2015 Last WO' 12/20/2015 42.76 2/120999 Vertical schemaSc(ectad') Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 9,728.0 5/31/2013 Rev Reason:WORKOVER;WELL lehallf 1/8/2016 HANGER;30.4- s SUSPENDED ILK- Casing Strings __ .: Casing Description OD(in) ID On) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread CONDUCTOR 16 15.062 42.8 119.0 119.0 62.58 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(1 Grade Top Thread SURFACE 7 5/8 6.875 34.6 3,251.2 2,309.9 29.70 L-80 BTC-MOD 11l3. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD(... Wt/Len(I.. Grade Top Thread I �` PRODUCTION 51/2 4.950 33.0 11,040.5 5,371.9 15.50 L-80 MOD 55"x35"@10277' Tubing Strings Tubing Description Strin Ma...ID(in) To Set Depth(ft.. (TVD) Wt(Ib/ft) Grade To Connection I" Wti 9 .', TUBING KILL 31/21 2.9921 pl ftKB(30.41Set Depth 7,946.414,006.6 9.30 L-80 I EUE 8rd i 6 STRING 2015 RWO € . Completion Details Nominal ID r I Top(ftKB) Top(WD)(ftKB) Top Incl I') Item Des Com (in) moi.CONDUCTOR;42.8-119.0 30.4 30.4 0.09 HANGER FMC TC-1A-EMS,11"x 3-1/2",EUE 8rd Top and Bottom, 2.992 7.115"OD EN, Tubing Description (String Ma...I ID(in) (Top(ftKB) Set Depth(ft...1Set Depth(TVD)(...IWt(Ib/ft) (Grade (Top Connection TUBING 31/2 2.992 9,833.0 10,280.01 4,945.3 9.30 L-80 EUE8rdMOD Completion Details Nominal ID ' s Top(ftKB) Top(TVD)(ftKB) Top Incl F) Item Des Corn (in) 10,153.1 4,877.0 58.26 SLEEVE-C BAKER CMU SLIDING SLEEVE w/CAMCO PROFILE 2.813 (CLOSED 1/12/2006) 10,254.8 4,931.6 56.96 NIPPLE CAMCO'D'NIPPLE 2.750 10,262.0 4,935.5 56.92 LOCATOR BAKER LOCATOR-SITS 1'ABOVE PROD CSG CSR 2985 10,263.5 4,936.3 56.91 SEAL ASSY BAKER 5.5"80-40 CASING SEAL ASSEMBLY 2.985 SURFACE;34.53,251.2- 1 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(WD) Top Incl Top(ftKB) (ftKB) CI Des Com Run Date ID(in) 8,283.0' 4,118.4 69.51 Cement BAKER 2AA 12/15/2015 Retainer 'CONDUCTOR SUBSIDENCE:Welded 11"x16" 9/2/2013 extension on top of existing conductor;raising back cement Retainer,6,263.0 !IIttA to original RKB / r 4 Perforations&Slots ,sroShot Dens Top(WD) Btm(WD) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com litg TUBING:9,0330 Iw 10,585.0 10,595.0 5,112.9 5,118.5 S-5,2N-320 11/13/2006 6.0 APERF 2.5"HSD BH,60 deg phase SLEEVE-C:10,153.1 10,610.0 10,650.0 5,126.8 5,149.1 S-3,2N-320 3/5/1999 4.0 IPERF 2.5"HC BHC,180 deg A ,. phase,orient*1-90 deg II),'+ from high side II' r* Stimulations&Treatments Min Top Max Btm Depth Depth Top(TVD) Btm(WD) GAS LIFT:10,203.1 AA Lr (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com A Ih 10,585.0 10,617.0 5,112.9 5,130.7 FRAC 1/16/2008 PLACED TOTAL OF 186,0008 OF 16/20 CERAMIC PROPPANT BEHIND PIPE W/9 PPA ON PERFS ++e 10,610.0 10,650.0 5,126.8 5,149.1 FRAC 3/14/1999 PLACED 93,0008 PROPPANT IN FORMATION r° °� Cement Squeezes AQ ,. Top(TVD) Btm(WD) A., � Top(ftKB) Btm(ftKB) (NAB) (ftKB) Des Start Date Com 9C 1s. 8,233.0 10,650.0 4,100.8 5,149.1 Cement 12/15/201 ALL PERFS CEMENTED DURING 2015 RWO NIPPLE:10,254.8 '42:' Squeeze 5 i 7,967.7 10,650.0 4,013.3 5,149.1 Cement 12/15/201 ALL PERFS CEMENTED DURING RWO 2015 Squeeze 5 Notes:General&Safety End Date Annotation N 7/17/2009 NOTE:View Schematic w/Alaska Schematic9.0 LOCATOR:10,2620 r SEAL ASSY:10,263.5 i ,, `rem 6 :frt/ w APERF;10,585.0-10,595.0 FRAC;10,585.0 yyy� , (PERF;10,610.0-10,650.0 + r FRAC;10,610.0 C. PRODUCTION 5.55,3.5'rly 10277';33.0-11,040.5 • . Loepp, Victoria T (DOA) From: Loepp,Victoria T (DOA) Sent: Tuesday,January 19, 2016 7:44 AM To: 'Coberly,Jonathan' Subject: RE: 2N-320 (PTD: 199-001) Form 10-403a Jonathon, Sorry for the late reply. A 10-407 is required on a suspension. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska satiMED MAY 1 9 2016 Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppaalaska.aov 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 Victoria Loepp at(907)793-1247 or Victoria.Loeoo@alaska.gov From: Coberly, Jonathan [mailtq:Janathan.Coberly@conocophillips.com] Sent: Friday, January 15, 2016 3:37 PM To: Loepp, Victoria T(DOA) Cc: Haggerty-Sherrod, Ann (Northland Staffing Services) Subject: RE: 2N-320 (PTD: 199-001) Form 10-403 Victoria, I was reviewing the approved 10-403 for 2N-320(PTD: 199-001)and had a question prior to sending in the requested 10- 407. It is written in the 10-403 to send in a 10-407 instead of the typical 10-404 form that I am used to submitting. Considering this well is a suspension and not a full P&A should we be submitting the 10-404 instead? I wanted to clarify since this was a little different than what I remember doing in the past. Thank you, Jonathan Coberly POP Project Lead ConocoPhillips Alaska, Inc. 700 G Street,ATO 1504 Anchorage,AK 99501 Office: 907-265-1013 Cell: 907-538-8398 1 • • From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Monday, December 14, 2015 6:05 PM To:Coberly,Jonathan<Jonathan.Coberly(Wconocophillips.com> Subject: [EXTERNAL]Re: 2N-320(PTD: 199-001) Form 10-403 Jonathan, Verbal approval is granted to proceed with the suspension of this well as outlined below. Please tag the TOC in addition to the pressure test outlined. Thanx, Victoria Sent from my iPhone On Dec 14, 2015, at 12:46 PM, Coberly,Jonathan<Jonathan.Coberly conocophillips.com>wrote: Yes. I will have my Admin get it on its way over there. Jonathan Coberly Senior Wells Engineer ConocoPhillips Alaska, Inc. 700 G Street,ATO 1504 Anchorage,AK 99501 Office: 907-265-1013 Cell: 907-538-8398 From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Monday, December 14, 2015 12:14 PM To:Coberly,Jonathan<Jonathan.Coberly@conocophillips.com> Subject: [EXTERNAL]Re: 2N-320(PTD: 199-001) Form 10-403 Can the sundry be delivered this afternoon? Sent from my iPhone On Dec 14, 2015, at 11:59 AM, Coberly,Jonathan<Jonathan.Coberly@conocophillips.com>wrote: Victoria, Please review and approve/revise in email to this request to suspend 2N-320 (PTD: 199- 001). The cement retainer should be ready to be set tonight or early morning tomorrow. Ann will have a paper copy sent to you via the normal delivery process soon. Thank you, Jonathan Coberly Senior Wells Engineer ConocoPhillips Alaska, Inc. 700 G Street,ATO 1504 Anchorage,AK 99501 Office: 907-265-1013 2 • • 0.),\ THE STATE Alaska Oil and Gas � � , of TT sTA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF f ALAS Fax: 907.276.7542 o_} q www.aogcc.alaska.gov En 43 Jonathan Coberly Sr. Wells Engineer �© I ConocoPhillips Alaska, Inc. I 11 9 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Tarn Oil Pool, KRU 2N-320 Sundry Number: 315-742 Dear Mr. Coberly: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy t. Foerster Chair DATED this IS day of December, 2015 Encl. RBDMS )i17 2015 • STATE OF ALASKA • RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION DEC 114 2015 APPLICATION FOR SUNDRY APPROVALS 9Ts `Z(! i5/ 20 AAC 25.280 AOGC 1.Type of Request: Abandon 1 .. Plug Perforations """ Fracture Stimulate 1....... Repair Well ("" Operations Shutdown 1"""" Suspend R Perforate P Other Stimulate l Pull Tubing 'P Change Approved Program 1- Plug for Redrill IT Perforate New Pool r Re-enter Susp Well J Alter Casing I— Other: 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc.. Exploratory F...... Development ',_ ' , 199-001 3.Address: 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 • Stratigraphic i'' Service Service 50-103-20287-00 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? none Will planned perforations require a spacing exception? Yes No ] 1 �`RVr� 2N-320 9. Property Designation(Lease Number): 10. Field/Pool(s): ADL0380054 • Kuparuk River Field/Tarn Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): ' 11,061' • 5,384' • 10627 - 5136 2800 psi r none Casing Length Size MD - TVD Burst Collapse - Structural - Conductor 76' 16" 118' 118' Surface 3,217' 7 5/8' 3,251' 2,310' Intermediate Production 11,008' 51/2" 11,040' 5372' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10585-10595 ' 5113-5118 3.5 L-80 10,280' 10610-10650 5127-5149 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Packers-None Packers N/A 12.Attachments: Proposal Summary 2 Wellbore schematic El 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory i Stratigraphic F..... Development ';;; Service 14. Estimated Date for 12/14/2015 15.Well Status after proposed work: / Commencing Operations: OIL WINJ WDSPL (...... Suspended i✓ 16.Verbal Approval: Date: /Z7/411 GAS r WAG r GSTOR F SPLUG GINJ r OpShutdown F""' Abandoned E. Commission Representative: (/L O C�P 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Jonathan Coberly Email Jonathan.Coberly(a�cop.com Printed Name Jonathan Coberly@265-1013 Title Sr.Wells Engineer I -- "'.-(< Q2--111-1s Signature Phone 265-1013 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 15 - -7442-.. Plug Integrity t BOP Test I" Mechanical Integrity Test ❑ Location Clearance ❑ Other: eUp frs ./ to ,,pvU 75f ["c ZSGo p5 ._y �h�1a nrr��N �r �lrst R8DMSSS1 ; 20 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Ri Subsequent Form Required: I0— 4G 1 APPROVED BY � , Approved by: alep SIONER THE COMMISSION Date: 1 -lSS;t F rm and Form 10-403 vised 11/2015 Rr*IvG4iNo lid for 12 months from t e dt2 Of approval. Attachments in Duplicate YT1. iZ/! /1�c��V// ?, 174141/"5 , 7z/V/'-- • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 12/14/2015 Commissioner Cathy Foerster State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner Foerster: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to suspend the Tarn Producer 2N-320(PTD: 199-001). Producer 2N-320 was spud in 1999 as a gas lifted Tarn producer from the Bermuda formation. A rig workover to pull and replace damaged production tubing was initiated on 12/1/2016. During the process to recover the damaged tubing multiple attempts to fish the tubing and ultimately mill over the tubing were unsuccessful to recover the heavily damaged tubing. The recovered tubing from 8,300' to 9,851' MD was found to be heavily damaged to the point that much of the tubing body was missing making it very difficult to fish and mill over. The current operation is to test the casing to ensure casing integrity to the depth of the fish and suspend the well from that point downward. Once a suitable location to set a cement retainer is located, the plan forward is to pump cement through the retainer to the perforations and to leave 50' of cement above the cement retainer. A kill string will be left in the well to aid in any future work to recover this well or plug and abandon the well entirely. If you have any questions or require any further information,please contact me at 265-1013 or Jonathan.Coberly@conocophillips.com. Sincerely, I Jonathan Coberly Senior Wells Engineer ConocoPhillips Drilling&Wells • • • 2N-320 Rig Workover, Suspension (PTD #: 199-001) Current Status: The well is currently being worked over to pull and replace tubing. Scope of Work: (1)Pressure Test Casing, (2) Set Cement Retainer, (3)Pump Cement, (4)Test Plug, (5) Run Kill String General Well info: MPSP: 2,800 psig(surface pressure recorded) Reservoir pressure/TVD: Bermuda—2,600 psig/4,533' TVD (11.0 ppg EMW)measured 10/5/2015 Currently using 11.6 ppg KWF Wellhead type/pressure rating: FMC Gen V, 11"5M Top x 11"5M Bottom Nabors 7ES BOP Configuration: Annular/VBR /Blind Rams/Mud Cross/VBR MIT results: TIFL—Failed(5/6/2015) Well Type: Producer Estimated Start Date: 12/14/2015 Production Engineer: David Lagerlef/Stephanie Pilch Workover Engineer: Jonathan Coberly(265-1013/Jonathan.Coberly@conocophillips.com) Proposed Procedure: Currently RIH with RBP on DP to ensure casing integrity through to fish depth at 9,850'MD. 1. Locate cement retainer set depth with RBP. POOH. 2. Test BOPE to 3,000 psi per AOGCC test frequency regulations. 3. RIH with cement retainer to set depth(planned to be between 8,300'MD and 9,850'MD). 4. Pump cement plan: a. 20 bbls spacer b. Casing volume from cement retainer to perforations +—50%excess Unislurry cement(15.8 ppg, Class G) c. Sting out of cement retainer and dump 50' of cement on top of cement retainer d. Circulate out excess cement e. Wait on cement 5. POOH laying down DP. 6. Pressure test casing and cement plug to 2,500 psig and record on chart recorder. Ta 7 P t 7. RIH with tubing kill string and land the hanger. RILDS's. 8. Install BPV. PT BPV. ND BOPE. 9. NU the tree. Pull BPV. Install tree test plug. PT tree and packoffs. 10. Circulate the well to corrosion inhibited seawater. Freeze protect. Set BPV. 11. RDMO. • ConocoPhillips 2015 PROPOSED COMPLETION Well: 2N-320 API: 501032028700 PTD: 199-001 Wellhead: FMC Gen V 5M Tree: 3 1/8"5M Conductor: 16"62.5#H-40 Welded to 119'RKB Surface Casing: 7 5/8"29.7#L-80 BTCM to 3,251'RKB A Production Casing: 5 1/2"15.5#L-80 BTCM to 10,263'RKB 3 1/2"9.3#L-80 EUE to 11,041'RKB Production Tubing:(Fish) 3-1/2"9.3#L-80 EUE-M to 10,280'RKB Stub at—9,851'RKB Perforations: MD Zone 10,585'-10,595' S-5 10,610'-10,650' S-3 1— Killstring set just above TOC Directional: 50'of cement on top of cement retainer set depth �"���`��``� Max Incline: 72.23° > 4_ Cement Retainer(set above any casing damage found; presumed to be between 8,300'MD-9,850'MD) Max Dogleg: 4.2 0/100FT 3 1/2"9.3#L-80 EUE-8RD(half of tubing body 111— circumference missing;collars intact;milled to 9,851'MD) ss .4— Baker CMU Sliding Sleeve,w/2.813"ID CAMCO Profile 1— CAMCO,KBG-2-9 GLM D rr: 4—2.75"ID'D'Profile Nipple y�.,......, A— 80-40 Seal Assembly Total Depth: 11,041'RKB Updated by:J.Coberly 12/14/2015 f KUP PROD 2N-320 ConocOPhillips $ Well Attributes Max Angle&MD TD • Alaika,Inc. Wellbore API/UWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Btm(ftKB) •Lnn 6..t.th, 501032028700 TARN PARTICIPATING AREA PROD 72 23 7,891.01 11,061.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 2N-320,9/23/201310.30:15AM SSSV:NIPPLE Last WO: 42.76 2/12/1999 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 9,728.0 5/31/2013 Rev Reason:Repair Conductor Subsidence osborl 9/23/2013 HANGER:30.4 Casing Strings �� Casing Description CONDUCTOR OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread 16 15.062 42.8 119.0 119.0 62.58 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 75/8 6.875 34.6 3,251.2 2,309.9 29.70 L-80 BTC-MOD Cas ng Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread PRODUCTION 51/2 4.950 33.0 11,040.5 5,371.9 15.50 L-80 MOD ® 5.5"x3.5"@ 10277 ij rip Tubing Strings LI _ Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..'Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING 31/2 2.992 30.4 10,280.0 4,945.3 9.30 L-80 EUE8rdMOD Completion Details Nominal ID ..... _ Top(ftKB) Top(ND)(ftKB) Top Incl(") Item Des Com (in) I III 30.4 0.09 HANGER FMC GEN V TUBING HANGER 3.500 h/s , /CONDUCTOR,42.8-119.0 I 502.3 502.3 1.85 NIPPLE CAMCO'DS'NIPPLE 2.875 10,153.1 4,877.0 58.26 SLEEVE-C BAKER CMU SLIDING SLEEVE w/CAMCO PROFILE 2.813 IIlltr. (CLOSED 1/12/2006) NIPPLE;502.3 i I 1 FM 10,254.8 4,931.5 56.96 NIPPLE CAMCO'D'NIPPLE 2.750 10,261.9 4,935.5 56.92 LOCATOR BAKER LOCATOR-SITS 1'ABOVE PROD CSG CSR 2.985 10,263.4 4,936.3 56.91 SEAL ASSY BAKER 5.5"80-40 CASING SEAL ASSEMBLY 2.985 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) CONDUCTOR SUBSIDENCE:Welded 11"x16" 9/2/2013 extension on top of existing conductor;raising back to original RKB rPerforations&Slots SURFACE;34.63,251.2+ Shot Den Top(ND) Btm(TVD) (shots# Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn III 10,585.0 10,595.0 5,112.9 5,118.5 S-5,2N-320 '11/13/2006 6.0 APERF 2.5"HSD BH,60 deg phase GAS LIFT;6.517.5 10,610.0 10,650.0 5,126.8 5,149.1 S-3,2N-320 3/5/1999 4.0 IPERF 2.5"HCBHC,180 deg 1I phase,orient+/-90 deg from high side Stimulations&Treatments Min Top Max Btm Depth Depth Top(ND) Btm(ND) (ftKB) (ftKB( (ftKB( (ftKB) Type Date Com 10,610.0 10,650.0 5,126.8 5,149.1 FRAC 3/14/1999 PLACED 93,000#PROPPANT IN FORMATION SLEEVE-C;10,153.1 'El- 10,585.0 10,617.0 5,112.9 5,130.7 FRAC 1/16/2008 PLACED TOTAL OF 186,000#OF 16/20 CERAMIC PROPPANT BEHIND PIPE W/9 PPA ON PERFS III Mandrel Details St ati C on Top(ND) Valve Latch Port Size TRO Run No Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date m GAS LIFT,m,zoa.o o I 1 6,517.5 3,504.3 CAMCO KBG-2-9 1 GAS LIFT DMY BTM 0.000 0.0 4/5/2006 2 10,203.1 4,903.5 CAMCO KBG-2-9 1 GAS LIFT OV BTM 0.313 0.0 4/8/2006 I Notes:General&Safety End Date Annotation 7/17/2009 NOTE:View Schematic w/Alaska Schematic9.0 s NII'F'LE.10,2548 ll LOCATOR;10261.9 , SEAL ASSY;10,263.4MO ' ,, as i i APERF;10,585.0.10,595.0 - FRAC;10,585.0 IPERF;10,610.0.10,650.0 FRAC;10,610.0, - PRODUCTION 5.5')3.5'@ 1027T;33.041,040 5- • I Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Monday, December 14, 2015 6:05 PM To: Coberly,Jonathan Subject: Re: 2N-320 (PTD: 199-001) Form 10-403 Jonathan, Verbal approval is granted to proceed with the suspension of this well as outlined below. Please tag the TOC in addition to the pressure test outlined. Thanx, Victoria Sent from my iPhone On Dec 14, 2015, at 12:46 PM,Coberly,Jonathan<Jonathan.Coberly@conocophillips.com>wrote: Yes. I will have my Admin get it on its way over there. Jonathan Coberly Senior Wells Engineer ConocoPhillips Alaska, Inc. 700 G Street,ATO 1504 Anchorage,AK 99501 Office: 907-265-1013 Cell: 907-538-8398 From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Monday, December 14, 2015 12:14 PM To:Coberly,Jonathan<Jonathan.Coberly@r onocophillips.com> Subject: [EXTERNAL]Re:2N-320(PTD: 199-001) Form 10-403 Can the sundry be delivered this afternoon? Sent from my iPhone On Dec 14, 2015, at 11:59 AM, Coberly,Jonathan<Jonathan.Coberly@conocophillips.com>wrote: Victoria, Please review and approve/revise in email to this request to suspend 2N-320 (PTD: 199- 001). The cement retainer should be ready to be set tonight or early morning tomorrow. Ann will have a paper copy sent to you via the normal delivery process soon. Thank you, Jonathan Coberly Senior Wells Engineer 1 XHVZE Pages NOT Scanned in this Well History ~ile This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE RESCAN Complete [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Beverly Mildred Daretha~ Date ~/--/.,~ Is/ ¢/~-._ [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Mddred Daretha Nathan Lowell Date Is~ STATE OF ALASKA • . ` Alt OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r Plug Perforations r Perforate r Other i_ Conductor Extension Alter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r _ 199-001 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-103-20287-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0380054 • 2N-320 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Kuparuk River Field/Tarn Oil Pool 11.Present Well Condition Summary: Total Depth measured 11061 feet Plugs(measured) None true vertical 5384 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 10263 true vertical 0 feet (true vertical) 4936 Casing Length Size MD ND Burst Collapse CONDUCTOR 75 16 118 118 1640 630 SURFACE 3217 7.625 3251 2310 6890 4790 PRODUCTION 11006 5.5 11040 5372 7000 4990 RECEIVED Perforation depth: Measured depth: 10585-10617, 10610-10650 SEP 16 2013 True Vertical Depth: 5113-5131, 5126-5149 ENE° ill J\I 1 4 .013 AOGCC Tubing(size,grade,MD,and TVD) 3.5, L-80, 10280 MD,4935 TVD Packers&SSSV(type,MD,and ND) SEAL ASSY-BAKER 5.5"80-40 CASING SEAL ASSEMBLY @ 10263 MD and 4936 TVD 12.Stimulation or cement squeeze summary:N/A Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r • Service r Stratigraphic r 16.Well Status after work: Oil r . Gas r WDSPL r Daily Report of Well Operations X GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-307 Contact Martin Walters/MJ Loveland Email N1878( cop.com Printed Name Martin Walters Title Well Integrity Projects Supervisor Signature 17/fG/(4-7/ 1' Phone:659-7043 Date 9/11/13 1," F Pfialt3 RBDMS SEP 187 (?( 4? Form 10-404 Revised 10/2012 Submit Original Only • • RECEIVED ConocoPhillips SEP 16 2013 P.O. BOX 100360 Alaska G ANCHORAGE,ALASKA 99510-0360 September 11, 2013 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Seamount: Enclosed please find the 10-404 Sundry for ConocoPhillips Alaska, Inc. well 2N-320, PTD 199-001, Sundry# 313-307 conductor extension. Please contact Martin Walters or MJ Loveland at 659-7043 if you have any questions. Sincerely, ,44—/ (),1440— Martin Walters ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 NSK Well Integrity Projects Supervisor . • • 2N-320 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/02/13 Welder fitted and welded 11"X 16"extension onto conductor for a total of 119'. • 2N-320 DESCRIPTION OF WORK COMPLETED SUMMARY • • 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: 2N-320 Run Date: 7/18/2009 December 1, 2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention o£ Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2N-320 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20287-00 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 ba ~' ~~ ~~ ~~m Date: ~iaSk~, bar{ ex la`~S ~G~~. i~Cl("ir`~;11~~°.~~" ~~~ ~~o~a Signed: . . ConocÓPhillips Alaska RëC!\VED SEP 1 2 2007 . 'on ",,,\(8 au & Gas Cons. CommlSSI Anchorage P.O. BOX 100360 ANCHORAGE, AlASKA 99510-0360 September 07, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 CANNED SEP 1 2 2007 Anchorage, AI( 99501 5 q.... e>ÐI 0 \ ~N.... ?JJ- Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells trom the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with a corrosion inhibitor, engineered to prevent water trom entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped on September 5,2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, \ß~/- ~end ConocoPhillips Well Integrity Field Supervisor ~ . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement DumDed cement date inhibitor sealant date ft bbls ft aal 2N-320 199-001 4" nfa 4" n/a 2 9/5f2007 2N-321 198-173 6" n/a 6" n/a 2 9/5/2007 2N-323 198-071 1" n/a 1" nfa 1 9/5/2007 2N-325 198-163 10" nfa 10" nfa 2 9/5/2007 2N-326 200-155 9" nfa 9" n/a 3.5 9f5/2007 2N-337 206-163 6" nfa 6" n/a 1 9f5/2007 2N-339 198-100 8" nfa 8" nfa 2.5 9/5/2007 2N-341 198-103 3" nfa 3" nfa 1 9/5/2007 2N-342 207-068 18" nfa 18" n/a 4.5 9/5/2007 2N-343 198-092 4" nfa 4" nfa 2 9/5/2007 2N-345 204-034 9" nfa 9" nfa 3.5 9/5/2007 Date 917f2007 e ConocóPhillips e Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 February 22, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 RtCË/I/ËD MAR 0 6· 'J{ A' lun . "'ks Oil & . ¡IQ Gas Cons. r; . AnChorage f1frrn¡gSion Subject: Report of Sundry Well Operations for 2N-320 (APD # 199-001) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforation and stimulation operations on the Kuparuk well 2N-320. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, )11. AI{~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad e e k 1:. \." 1:.1 v ..... u MAR 0 6 2006 STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Cons. Commission REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 . Other 0 Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Ope rat. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: 0 0 .,' ConocoPhillips Alaska, Inc. Development Exploratory 199-0011 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20287 -00 7. KB Elevation (ft): 9. Well Name and Number: ". RKB 38' 2N-320 8. Property Designati~n: 10. Field/Pool(s): ADL 380054, ALK 4602 Kuparuk River Field 1 Tarn Oil Pool' 11. Present Well Condition Summary: Total Depth measured 11061' feet true vertical 5384' ' feet Plugs (measured) Effective Depth measured 10627' feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 110' 110' SURFACE 3227' 7-5/8" 3265' 2315' PRODUCTION 10218' 5-1/2" 1 0256' 4932' LINER 764' 3-1/2" 11 040' 5372' Perforation depth: Measured depth: 10585'-10595', 10610'-10650' true vertical depth: 5113'-5118',5127'-5149' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 10279' MD. Packers & SSSV (type & measured depth) no packer Cameo OS nipple @ 502' 12. Stimulation or cement squeeze summary: Intervals treated (measured) refer to attachment RBDMS BFL MAR 0 6 2006 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubino Pressure Prior to well operation 1267 3282 661 -- 252 Subsequent to operation 1211 3035 1494 -- 260 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: Oil0 GasD WAG 0 GINJD WINJD WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Contact Mike Mooney @ 263-4574 Printed Name Mike Mooney Title Wells Group Team Lead .,lfR/o?, Signature !I/. ,t/ÛVT' Phone Date PreDared bv Sharon AlIsuD-Drake 263-4612 . J (ijh", ~j~L)¡11~ . . Form 10-404 Revised 04/2004 ORIGINAL .~ ,¡ .~4Ç Submit Onglnal Only ~ ~;6G e 2N-320 Well Events Summary e DATE Summary 1/9/06 PERFORMED A TBG WASH IN 3.5" TBG WITH HOT DIESEL (125 F). WASHED PAST GLM @ 6517' AND JEWELRY FROM 10,000' -10,280' CTD WITH 2" JET SWIRL NZL. 1/10/06 TAGGED @ 10633' RKB, EST. 17' FILL. GAUGED TBG TO 2.78" TO D NIPPLE @ 10254' RKB. SET CAT SV @ 10254' RKB & PULLED OV @ 10203' RKB. IN PROGRESS. 1/11/06 LOADED IA WITH DSL. SET DV @ 10203' RKB. ATTEMPTED TEST CSG, COMM WITH TBG. CYCLED CMU @ 10153' RKB OPEN, ATTEMPT CLOSE. IN PROGRESS. 1/12/06 PULLED 2.75" CAT SV @ 10254' RKB. DISPLACED WITH DSL WHILE BRUSHING CMU @ 10153' RKB. CLOSED SAME. TESTED CSG 2000 PSI, GOOD. 1/13/06 PERFORATION FROM 10,585 - 10,595 FT, TOTAL 10', USING 21/2" HSD BH, 6 SPF, 60 DEGREE PHASING. CHARGES: 10.5 GM RDX, PENETRATION 5.8", BH 0.62". CCL TO TS: 3.2', STOP DEPTH 10,581.8 FT. UNABLE TO REACH INITIAL INTERVAL OF 10,610-10,620 DUE TO FILL. TAGGED BOTTOM AT 10,617 FT. 1/16/06 PUMP FRACTURE TREATMENT WITH A PRE-PAD BRACKETFRAC. PUMP JOB USING 50# XL GEL @ 20 BPM. PLACE A TOTAL OF 186,000 LBS OF 16/20 CERAMIC PROPPANT BEHIND PIPE WITH 9 PPA ON PERFS. FLUSH JOB TO COMPLETION LEAVING 20 BBLS OF DIESEL IN WELL FOR FREEZE PROTECT. 1/17/06 CLEANED FILL TO HARD TAG AT 10777' CTMD WITH GELLED DIESEL AND N2. LEFT WELL LOADED WITH DIESEL. 1/18/06 TAGGED FILL @ 10,632' RKB, 18' OF FILL OVER BTM PERF'S, SET CATCHER @ 10,254' RKB, PULLED DV @ 10,203' RKB, IN PROGRESS 1/19/06 SET 1" OV @ 10,203' RKB, PULLED CATCHER @ 10,254' RKB. JOB COMPLETE. 1/28/06 UNABLE TO DRIFT PAST 8081' WLM W/2.75" CATCHER SUB, 2.79" GAUGE RING OR 2.67" GAUGE RING. APPEARS TO HAVE EXCESSIVE AMOUNT OF FRAC SAND STILL IN WELLBORE. 1/30/06 CLEANED OUT FILL TO 10,770' CTM W/ SLICK DIESEL, DIESEL GEL, AND NITROGEN USING A 2" JETSWIRL NOZZLE. WELL LEFT SHUT IN AND LOADED W/ DIESEL. NOTE: OTIS ADAPTER INSTALLED FOR SLlCKLlNE. 1/31/06 SET CATCHER @ 10254' RKB. PULLED OV @ 10203' RKB, GOOD CONDITION. IN PROGRESS. 2/2/06 SET OV @ 10203' RKB. PULLED CATCHER. FOOTAGE COUNTER PROBLEMS PULLING OUT OF HOLE, PARTED WIRE @ SURFACE LEAVING TOOL STRING IN WELL. IN PROGRESS. 2/3/06 RECOVERED TOOL STRING FROM 10192' WLM W/ EMPTY CATCHER SUB. TAGGED @ 10652' RKB, EST. 2' RA THOLE. 2/5/06 RECOVERED 16' OF .108" WI RE FROM WELL. TAGGED @ 10397' RKB, EST. 252' FILL. SET 5/16" OV @ 6517' RKB. ConocoPhillips Alala, Inc. e KRU ~-320 2N-320 API: 501032028700 Well Tvoe: PROD Anç¡le @ TS: deç¡@ TUBING SSSV Type: NIPPLE Orig 211211999 Angle @ TD: 54 deg@ 11061 (0-10279, Completion: 00:3.500, 10:2.992) Annular Fluid: Last W/O: Rev Reason: TAG FILL Reference Loa: Ref Loç¡ Date: Last Update: 10/27/2005 Last Taç¡: 10627 TD: 11061 ftKB SURFACE (0-3265, 00:7.625, Wt:29.70) Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 118 118 62.58 H-40 WELDED SURFACE 7.625 0 3265 2315 29.70 L-80 BTC-MOD PRODUCTION 5.500 0 10256 4932 15.50 L-80 BTC-MOD LINER 3.500 10276 11040 5372 9.30 L-80 EUE 8rd Tubina Strina - TUBING Size Top I Bottom I TVD I Wt I Grade I Thread 3.500 I 0 I 10279 I 4945 I 9.30 I L-80 I EUE 8rd 'ROOUCTlON Peñorations Summary (0-10256, Interval TVD Zone Status Ft SPF Date Type Comment 00:5.500, Wt:15.50) 10610 - 10650 5127 - 5149 0 40 4 3/5/1999 IPERF 2.5" HC BHC; 180 deg phasing, oriented +1- 90 deg from . h side Stimulations & Treatments Interval I Date I Type I Comment 10610 - 10650 I 3/14/1999 I FRAC I Frac; placed 93 Mlbs prop in formation. Gas lift MandrelsNalves St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv SLEEVE Mfr Run Cmnt 10153-10154, , 1 6517 3504 CAMCO KBG-2-9 CAMCO DMY 1.0 INT 0.000 0 211211999 00:3.500) .. .' 2 10203 4904 CAMCO KBG-2-9 CAMCO OV 1.0 INT 0.313 0 3/18/1999 . .- 1 ; Other :pluas, eauip., etc.) - JEWELRY ---.----- ... ..--..--.-...--..-...-....-.--... -.-.- -~.. . .. "'_..__"'n__n : Depth TVD Type Description ... -----¡--fiy- -- ': 502 502 NIP CAMCO DS 2.875 10153 4877 SLEEVE BAKER CMU with CAMCO profile 2.813 10254 4931 NIP CAMCO "D" nipple 2.750 10261 4935 SEAL BAKER 5.5" 80-40 casinç¡ seal assembly 2.985 General Notes Gas Lift ~ Date Note : 6/11/1999 Cut paraffin from surface to 3100'. MandrelNalve 2 0/30/199~ Cut paraffin from surface to 3800'. 10203-10204, .. 1/17/2000 Cut paraffin from surface to 4000'. 00:4.725) 3/11/2000 Cut paraffin from surface to 4000'. 121221200C Obtained SBHP (â) 10480' = 1695 psi & 10580' WLM = 1712 psi; 133 deg F. NIP- . 10254-10255, 00:3.500) SEAL - . ...ø___ 10261-10262, 00:4.000) FRAC ~ ~ 10610-10650) / ) Perf (- =S: :10610-10650) / -':L LINER :10276-11040, 00:3.500, Wt:9.30) A 199-001-0 KUPARUK RIV U TARN 2N-320 50- 103-20287-00 Roll #1: Start: Stop Roll #2: Start Stop MD 11061 TVD 05384 Completion Date: .,~99 Completed Status: l-OIL PHILLIPS ALASKA INC Current: T Name Interval Sent Received D 9223 ~2~ SPERRY MPT/GR/EWR4/CNP/SLD OH 6/22/99 6/29/99 L CBL/SCMT ~AL 10240-10780 o.~'~ CH 5 3/12/99 3/18/99 L DGR/CNP/SLD-MD ~4~AL 3265-11061 .a~d_ OH 7~8/99 7/8/99 L DGR/CNP/SLD-TVD ~AL 2314-5383 [//.~ [,.. ~ OH 7/8/997/8/99 L DGR/EWR4-MD t,I~NAL 3265-11061 ~/ OH 7/8/99 7/8/99 L DGR/EWR4-TVD JAL 2314-5383 OH 7/8/99 7/8/99 L SCMT /~AL BL(C) 10240-10780 3/3/99 CH 5 6/8/99 6/16/99 R SRVY RP'r .~RRY 0-11061 OH 2/22/99 2/24/99 T/C/D _ Thursday, February 01, 2001 Page I of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Dan Seamount, Commissioner Blair Wondzell, -~~ P. I. Supervisor FROM: John Crisp? ~,/~ C,, SUBJECT: Petroleum InSpector DATE: July 20, 2000 Safety Valve Tests Kuparuk River Unit Tarn Field 2N & 2L Pads July-20~ 2000: I traveled to Phillips Alaska's Kuparuk River Unit Tarn Field to witness the semi-annual Safety Valve System tests on Pads 2N & 2L. Testing went well with only one failure on 2L Pad witnessed. No failures were witnessed on 2N Pad. The AOGCC test report is attached for reference. SUMMARY: I witnessed the semi-annual SVS tests on KRU's Tarn Pads 2N & 2L. 2N Pad, 9 wells, 18 components tested. No failures. 2L Pad, 6 wells, 12 components tested. 1 failure. 8% failure rate. Attachments: SVS Tarn KRU 2N & 2L 7-20-00jc cc;. :NON-GONFIDENTIAL SVS Tam KRU 2lq & 2L 7-20-00jc.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Inc Operator Rep: Ernie Bamdt AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: Tam, Kuparuk River, 2N Separator psi: LPS 94 ' HPS 7/20/00 Well Permit Separ Set L/P Test Test Test oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code GAS or CVC~,g 2N-307 1990170 2N-308 ~1990100 ~' 94 70: 65 p p OIL 2N-309 1990210 2N-313 1980910 94 70 70 p p OIL 2N-315 1981900 2N-317 1981430 94 70 70 p p OIL 2N-319 1981970 _ ~ 1990010 9~4 70 6~ p p _ OIL 2N-321A 1981730 2N-323 1980710 94 70 70 p p OIL 2N-325 1981630 2N-329 1980670 94 70 70 p p OIL 2N-331 1981170 2N-335 1982040 94 70 70 p p OIL 2N-337A 1981220 2N-339 1981000 2N-341 1981030 94 70 65 V p OIL 2N-343 1980920 2N-345 1981130 2N-347 2000630! 94 70 60 p p OIL Wells: 9 Components: 18 Failures: 0 Failure Rate: 0.0% [] 90 t)av Remarks: n/on/an Pa~e 1 of 1 - S¥S Tarn _KRU 2N 7-20-00jc.xls Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Inc Operator Rep: Emie Bamdt AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: Tarn, Kuparuk River, 2L Separator psi: LPS 94 HPS 7/20/00 Wellr permit Separ Set L/P- Test Tess Test oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code GAS or CYCLE 2L-305 1982400 94 70 60 P 4 OIL 2L-307 1982560 94 70 - 70 p p OIL 2L-313 1982190 94 70 651 p p OIL 2L-315 198-21~80! 94 70 70 p p OIL 2L-321 1982620 2L-323 1982510 2L-325 1982090 · 94 70 65 p p OIL 2L-329A 1982250 800 700 700 p p GAS Wells: 6 Components: 12 Failures: 1 Failure Rate: 8.0% [390 Day Remarks: 7/27/00 Page t of ~ r-: SVS_ :Tm_ KRU 2L 7-20-00jc.xls GeoQuest 3940 Arctic Blvd, Suite $00 Anchorage, AK 99503-5711 AT[N: Sherrle NO. 12852 Company: Field: Alaska Oil & Gas Cons Comm Attn: Loft Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) Well Job # Log Description Date Bluellne Sepia CD B-10 PSP-FSPL 991008 1 ! B-21 PSP-DEFT PL 990928 1 I B-21 PS P-D EFT/IM'AG ES 990928 1 1 E-28A PSP-LEAK DETECTION LOG 990929 1 1 D-10 .~1:.~'~ 99333 CNTD 990828 1 1 ! H-25 ..~ ~"~'~ 99337 CNTD 990829 1 1 1 -- , PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: 1 O/12/99 C~ BP Exploration (Alaska) Inc. Petrotectnlcal Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: RECEIVED 0ci- 2, 7 1999 Alnska 0tl & (~as Con~, Commi~ion 4 I Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 0 Iq I I--I--I N I~ ~lqVlC~m V~':I,I, L(~ TRANSMrI*rAL To: State of~ Alaska Oil and Gas Conservation Corem_ Att~: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 uly s, 1999 RE: MWD Formation Evaluation Logs 2N-320, AK-MM-90068 The teclmical data listed below is being submitted herewitlx Please address any problems or concerns to the attenti~ of. Tun Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, ~G, Anchorage, AK 99518 2N~320: 2" x 5" MD Resistivity & Cramma Ray Logs: 50-103-20287-00 2" x 5" TVD Resistivity & Ganm~ Ray Logs: 50-103-20287-00 2" x 5" MD Neutron & Density Logs: 50-103-20287-00 2" x 5" TVD Neutron & Density Logs: 50-103-20287-00 1999 Bhlelhle Folded Sepia I Bkldhle 1 Folded Sepia 1 Btueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Siiverado Way, Suite G . Anchorage, Alaska 99518 * (907) 273-3500 . Fax (907) 273-3535 ~1~I,I, IX)C TRANSMITTAL To: State of Alaska Su~ 22, 1999 Alaska Oil and_Gas Conservation Conmr Atm.: Loft Taylor 3001 Porcupine Dr. ~ra~e, Alaska 99501 RE: MWD Formation Evahutfion Logs 2N-320, AK-MM-90068 1 LDWG formatted ~ with verification listing. API~: 50-103-20287~ PLEASE ACKNOWLEDG~ RECEIPF BY SIGNING AND RETURNING THE A~FACHF~D COPY OF THE ~AL LETTERTO Tm~ A~ Sperry-Stm ~ Servi~e Atttr ~un Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 RECEIVED 5631 Silvemdo Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 6/8/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrle NO. 12633 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk/Tarn Pool/West Sak Well Job # Log Description Date Color Print 2T-210 99240 CBL W/PSP/SCMT 990523 1 2N-320 99241 SCMT 990303. 1 2L~323 b,~ c... 99239 CBT W/PsP/SCMT 990221 1 lC-18 99243 CBT W/PSP/SCMT 990402 1 1 D- 132 L~ t ~ 99248 SCMT 990216 1 1D-125 99249 CBT W/PSP/$CMT 990220 1 1D.- 114 I,,k ~ c. 99246 CBT W/PSP/SCMT 990421 1 I'D- 128 99247 $CMT 990215. 1 1D- 122 ~ I c_. 99244 CBT W/PSP/SCMT 990226 1 1D- 111 L,~.~ c 99245 CBT W/PSP/SCMT 990415 1 lC- 14 cc ~ ¢. 99242 SCMT 990122 1 SIGNE~~'~_~~~. DATE: Please sign and return one copy of this transmittal to Sherrle at the above address. Thank you. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 31, 1999 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2N-320 (Permit No. 99-01) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on Tam 2N-320. If there are any questions, please call 263-4603. Sincerely, P. Mazzolini Tam Drilling Team Leader PM/skad RECEIVED MAR 3'J 1999 Alaska Oil & Gas Cons. Commissior~ Anchorage STATE OF ALASKA _. ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Stalus of well Classification of Service Well O,I [] Gas [] Suspended [] Abandoned [] Sen/ice [] 2 Name of Operator 7. Permit Number ARCO Alaska, Inc 99-01 3~ Address 8 APl Number P O. Box 100360, Anchorage, AK 99510-0360 50-103-20287 4. Location of well at surface I C~ ~, 9. Uniter Lease Name 58' FNL, 748' FEL, Sec. 3, TgN, R7E, UM r ~ -~,u~ I ~ Kuparuk Rwer Unit At Top Pmduang Interval i ~ ~ ! 10. Well Number 2122'FSL, 1808'FWL, SEC33, T10N, R7E, UM i~!~'.~ - 2N-320 At Total Deplh ' . . ~11. Reid and Pool 2255' FSL, 1238' FWL, SEC 33, T10N, R7E, UM _ Kuparuk River F~eld 5 Elevabon in feet (~ndEcate KB, DF, etc ) ' ' 16' Leas~ Desl§nation and Serial No. RKB 38 feetI ADL 380054 ALK 4602 Tam -I;lw~-t,,Oil Pool '12 Date Spudded 13 Date T D. Reached L 14 Date Comp, Susp Or Aband. 115. Water Depth, ~f offsh°re 16. No. of Complehons January 25, 1999 February 8, 1999 February'11, 1999 I N/A feet USE 1 i7 Total Depth (MD + TVD) 18 Plug Bacl~ Depth (MD + TVD) 19. D~reclion~ Survey 120 Depth where SSSV sel 21. Thmkness of Permafrost 11061' MD / 5384' TVD 10914' MD / 5299' TVD YES [] No []I N/A feet MD 1227' (approx) 22 Type Electric or Other Logs Run GR/Res/Dens, CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT GRADE TOP Bo-froM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16' 62 5# H-40 Surface 110' 24' 9 cu yds Oregon Portland Type III 7 625' 29 7# L-80 Surface 3253' 9 875' 394 sx AS III L, & 251 sx Class G 5 5' X 15 5# L-80 Surface 10256' 6.75' 248 s_x Class G _ 3 5' 9.3~ L-80 10256' 11040' 6.75' (included above) ODIC"II IAI I\IUIi / L 24. Perforal~ons open to Producl~on (MD + TVD of Top and Boltom and 25. TUBING RECORD interval, s~e and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2' 10280' 10256' (CSR) 10610'-10650' MD 5127'-5149' TVD 4 spf 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10610'-10650' MD see attac~hment ~ E~ ~" ' VJ~,~. ~ ~i 27 pRODUCTION TEST "'" Date First .roductio. Method of Operation ,Flowing. gas hft, etc) ~Ja~J(a March 21, 1999 FIo~ng Date of Test Hours Tested Product]on for OIL-BBL GAS-MCF WATER-BBL CHOKE 81ZE IGAS-OIL 8/21/1999 6.0 Test Penod> 102 157 75 0l i538 Flew Tubing Cesmg Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY- APl (cerr) Press 322 psi 0 24-Hour Rate > 407 626 300 0 28. CORE DATA Brief descriptmn of lithology, porosity, fractures, apparent dips and pressence of od, gas or water. Submit core chEps * Thru 10-407 is submitted as directed per the 10-401 form approved (Permit ~99-01) RECEIVED Form 10-407 Rev 7-1-80 CONTINUED ON REVERSE SIDE =ate Alaska Oil & {las Cons. Oommi~sion Anchorage GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data) all fluids recovered and grawly. MEAS. DEPTH TRUE VERT. DEPTH GOR, and lime of each phase. T-3 10352' 4985' T-2 10706' 5181' Annulus left open - freeze protected with dies 31 LIST OF A'I-rACHMENTS Summary of Daily Operations and D~rectional Survey 32. I hereby ce~fy that the following is true and correct to the best of my knowledge Signed ~J'J~-~ ~~ 'lille Tam Drlllinq Team Leader Date '~/~0/C~ Paul Maz~.oll.~ ~ Prepared by Sharon AIIsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska Item 1' Classification of Service wells: Gas injection, water injection, steam ~njection, a~r ~njection, salt water disposal, water supply for injection, observation, injection for in-situ combustion Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given ~n other spaces on this form and in any attachments Item 16 and 24: If this well is completed for separate production from more than one interval (multiple complebon), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submrt a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.) Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool Item27: Method of Operation Flowing, GasLIft, RodPump, Hydraulic Pump, Submersible, Waterlnjec~n~~aJr~r~D Shut-in, Other-explain Item 28: If no cores taken, indicate "none" vIkR 3 'i999 Form 10-407 Alaska Oil & Gas Cons, Commission Anchorage Date: 3/9/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:2N-320 WELL ID: AK9797 TYPE: AFC: AK9797 STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD:01/25/99 START COMP: RIG:POOL 6 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20287-00 01/24/99 (D1) TD: 110'(110) SUPV:M. WINFREE MW: 10.1 VISC: 92 PV/YP: 17/36 Accept rig @ 0001 hrs. 1/24/99. Rig up. APIWL: 12.0 01/25/99 (D2) TD: 278'(168) SUPV:M. WINFREE MW: 10.0 VISC: 88 PV/YP: 19/31 DRILLING @ 600' APIWL: 0.0 Continue to rig up. Function test diverter. Pre-spud meeting. Spud in @ 2130 hrs., drilling 9.875" hole to 278' 01/26/99 (D3) MW: 10.2 VISC: 56 PV/YP: 17/28 TD: 2120'(1842) RIH, PICKING UP SINGLES. SUPV:DAVE BURLEY / RICK OVERSTREET Drill from 278' to 2120' APIWL: 8.6 01/27/99 (D4) MW: 10.2 VISC: 75 PV/YP: 23/24 APIWL: 6.8 TD: 3265'(1145) CIRC AND COND MUD. SUPV:DAVE BURLEY / RICK OVERSTREET Wiped hole to 375', no problems pulling out. RIH, worked pipe through tight spot @ 800'. Washed and reamed through tight spot @ 1460' Drill from 2120' to 3265' 01/28/99 (D5) MW: 10.2 VISC: 74 PV/YP: 25/28 TD: 3265'( 0) CIRCULATE FOR CEMENT JOB. SUPV:DAVE BURLEY / RICK OVERSTREET Run 7-5/8" casing. APIWL: 6.2 01/29/99 (D6) MW: 10.2 VISC: 58 PV/YP: 20/18 TD: 3265'( 0) NU BOPE. SUPV:DAVE BURLEY / RICK OVERSTREET Finished running 7-5/8" casing. Pump cement. APIWL: 7.4 01/30/99 (D7) MW: 9.3 VISC: 42 PV/YP: 11/13 TD: 3265'( 0) TESTING BOPE. SUPV:DAVE BURLEY / RICK OVERSTREET NU BOPE and function test. APIWL: 8.0 01/31/99 (D8) MW: 9.3 VISC: 45 PV/YP: 12/14 TD: 3265'( 0) PU AND MU BHA. SUPV:DAVE BURLEY / RICK OVERSTREET Test BOPE to 300/3500. APIWL: 7.8 'Date: 3/9/99 ARCO ALASKA INC. Page: 2 WELL SUMMARY REPORT 02/01/99 (D9) MW: 9.3 VISC: 43 PV/YP: 12/14 APIWL: 8.0 TD: 3265'( 0) RIG REPAIRS, WORKING ON TOP DRIVE. SUPV:DAVE BURLEY / RICK OVERSTREET Tagged cement stringers @ 3041'. Circ out cement contaminated mud. Clean out stringers from 3041' to 3068' Top drive hydraulic system failed work on top drive. 02/02/99 (D10) MW: 9.3 VISC: 44 PV/YP: 12/14 APIWL: 8.0 TD: 3265'( 0) TROUBLE SHOOTING FROZEN CHOKE AND CHOKE LINES. SUPV:DAVE BURLEY / SCOTT REYNOLDS Pipe handler not working. Repair top drive parts. 02/03/99 (Dll) MW: 9.4 VISC: 46 PV/YP: ~7/18 APIWL: 5.4 TD: 4771'(1506) SUPV:DAVE BURLEY / SCOTT REYNOLDS Drilling cement, float collar and shoe from 3120' to 3265' Drill 20' new formation. Calibrate stand pipe press. guages. Steam frozen kill line HCR valve until operable. Run LOT to 16.0 ppg EMW. Drill from 3285' to 4771' 02/04/99 (D12) MW: 9.4 VISC: 47 PV/YP: 18/20 APIWL: 5.4 TD: 5992'(1221) DRILLING SUPV:DAVE BURLEY / SCOTT REYNOLDS Drill from 4771' to 5985'. Check for flow, well static. CBU. 45 units gas @ BU. Very few bubbles breaking out at surface. Drill from 5985' ~o 5992'. 02/05/99 (D13) MW: 9.4 rISC: 46 PV/YP: 16/21 APIWL: 5.2 TD: 6927'(935) TRIPPING IN THE HOLE SUPV:DAVE BURLEY / SCOTT REYNOLDS Drill from 5992' to 6927'. Drilling erratic. POOH. 02/06/99 (D14) MW: 9.5 VISC: 47 PV/YP: 19/20 APIWL: 5.6 TD: 8357'(1430) MAKING HOLE SUPV:DAVE BURLEY / SCOTT REYNOLDS Rebuilt bit and new mud motor. Drill from 6927' to 7303' Circulate, hole loaded up. Lost 40 bbls. Pump @ reduced rate of 4 bbl/min. Increased slowly back to drilling rate of 6.4 bbls/min. Hole stabilized. Drill from 7303' to 8357'. 02/07/99 (D15) MW: 9.6 VISC: 43 PV/YP: 17/17 APIWL: 5.6 TD:10212'(1855) DRILLING PRODUCTION HOLE FROM 10,-680' SUPV:DAVE BURLEY / SCOTT REYNOLDS Drill froTM 8357' to 9367'. Perform LOT, 11.0 ppg3EMW. Drill from 9367' to 10212' 02/08/99 (D16) MW: 9.6 riSC: 44 PV/YP: 14/16 APIWL: 5.2 TD:l1061'(849) TRIPPING OUT OF HOLE SUPV:DAVE BURLEY / SCOTT REYNOLDS Drill from 10212' to 11061' Pump hi-vis Sweep and circulate. Date: 3/9/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 02/09/99 (D17) MW: 9.7 VISC: 47 PV/YP: 19/18 TD:l1061' ( 0) RIH W/PRODUCTION CASING. SUPV:FRED HERBERT / RICK OVERSTREE Run 3.5" casing and 5.5" casing. APIWL: 5.2 02/10/99 (D18) MW: 9.7 VISC: 40 PV/YP: 15/12 APIWL: 8.2 TD:ll061'( 0) INSTALL PACK OFF SUPV:FRED HERBERT / RICK OVERSTREE Run 5.5" casing. Break circ slowly. Begin losing returns. 02/11/99 (D19) MW: 8.5 VISC: 28 PV/YP: 1/ 0 TD:ll061'( 0) FREEZE PROTECT 3.5" X 5.5" ANNULUS SUPV:FRED HERBERT / RICK OVERSTREE Run 3.5" tubing. APIWL: 0.0 02/12/99 (D20) TD:ll061'( 0) MW: 8.5 VISC: 28 PV/YP: 1/ 0 RIG RELEASED @ 21:00. APIWL: 0.0 SUPV:FRED HERBERT / RICK OVERSTREE Pump diesel for freeze protect. ND BOP. NU tree and test to 250/5000'psi. Release rig 2/12/99 @ 2100 hrs. Date 03/05/99 Well Nam 2N-320 Service Type ELECTRIC LINE Upcoming Desc of Work INITIAL PERFORATIONS. Supervisor SMITH Complete r~' Accident r- Injury ~-- Spillr- Summary Job Num 0217991506.1 Unit 2128 AFC AK9797 0 Prop 180KNU Uploaded to S Contractor Key Person SWS-ELMORE Successful r~- Initial Tbg Press 0 Initial Int Csg Press 0 Initial Out Csg Press 350 Final Tbg Press 800 Final Int Csg Press 800 Final Out Csg Press 350 PERFORATED TARN SANDS. 10,610'-10,650' WITH 2.5" HOLLOW CARRIER 4 SPF, BIG HOLE CHARGES, 180 DEG. PHASIN SPF +/- 90 DEG F! HIGH SIDE. [Pert] Date printed: 03112/99 at: 14:53:21 ARCO Alaska, Inc. ~ WELL SERVICE REPORT ~ ,~ 2N-320 WELL JOB SCOPE JOB NUMBER 2N-320 DRILLING SU PPORT-CAPITAL 0217991506 1 DATE DAILY WORK UNIT NUMBER 03/14/99 FRACTURING DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 16 YESI YES DS-GALLEGOS FERGUSON FIELD AFC.~ CC~ Signed ESTIMATE AK9797 180KNU2TN Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 430 PSI 0 PSI 600 PSI 0 PSII 0 PSII 0 PSI DAILY SUMMARY RU DOWELL, PT 9250 PSI,PUMP BREAKDOWN AT 30 BPM SD. ISIP=630 PSI. FG=0.58 FOLLOW WI DATAFRAC. EFFICIENCY =34% CLOSURE 13.8 MIN ~ 780 PSI. PUMP FRAC USING 650 BBL PAD. SCREENOUT WITH 6.0 PPA AT PERFS, 92705 ~S BEHIND PIPE, LEAVING 19536 NS IN PIPE, PULL TREESAVER; ALL RUBBERS LEFT IN WELL[Frac-Refrac] TIME 08:15 10:45 :45 12:10 12:25 12:38 13:21 13:30 14:15 15:15 15:45 16:53 19:32 LOG ENTRY_ ARRIVE LOCATION, DOWELL PREPARING TO SPOT EQUIPMENT, MEI- I WITH RIG SUPERVISOR AND DISCUSS JOB CONDUCT SAFETY MEETING SET TREESAVER, ATTEMPT TO PRESSURE TEST LINES TO 8700 PSI. SD CIO RUBBER GASKI- I IN SWIVEL ABOVE TREESAVER. PRESSURE TES'~-TO 9250 PSI PERFORM HIGH RATE BREAKDOWN,AT3OBPM WITH t50 BBLS SLICKWATER. PERFORM SDT. ISIP=630 PSI, FG=0.57 PSI/FT, EXCESS FRICTON =1524~P. Sl AT30 BPM START SCOUR STAGES AT15 BPM, PUMP 5OBBLS 1PPA, 50 BBL SPACER, 50 BBLS 2 PPA AND DISPLACE WITH 150 BBLS GEL WATER PERFORM 6DT FOLLOWING SCOUR STAGES~ FG=0.58 PSlII- I, ExcEss FRICTION =211 PSI PERFORM PULSE TEST, POSSIBLE C~OSURE AT 570 PSI. PUMP 300 BBL DATAFRAC, SD FOR ANALYSIS DATAFRAC INDICATED CLOSURE AT 13.8 MINUIES, CLOSURE PRESSURE=780 PSI;EFFICIENCY@34%. ADJUST PAD VOUMEFOR PROPPED FRAC TO650 BBLS START FRAC AT 15 BPM- SCREEN-OUT WITH 6.0 PPG AT PERFS, TOTAL PROPPANT BEHIND PIPE=92705 #'S, PROPPANT LE~- I IN PIPE=19;536ff'S, TOTAL SLURRYPUMPED IN WELL 1386 BBLS REMOVE TREESAVER, ALL RUBBERCUPS LEI- I IN HOLE 22-Feb-99 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2N-320 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 11,061.00' MD 0f apphcable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) FEB 24 1999 5631 Silverado Way, Suite G * Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company Prudhoe Bay Unit Alaska State, Plane Zone 4 Kuparuk,2N, Slot 2N-320 2N-320 Job No. AKMM90068, Surveyed: 25 January, 1999 ORIGINAL RECEIVED FEB 24199~ SURVEY REPORT 22 February, 1999 Your Ref: API.501032028700 KBE-156.77 Surface Coordinates: 5911950.02 N, 460844.75 E (70° 10' 13.3930" N, 150° 18' 54.4521" I/If) Survey Ref: avy8245 Sperry-Sun Drilling Services Survey RePort for 2N-320 Your Ref'. API-501032028700 Job No. AKMM90068, Surveyed: 25 January, 1999 Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 2N Meaaured Sub-Sea Vertical Local Coordinates Global Coordinatea Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eaatings Northlngs Eaatlngs . Rate Section (ft) (ft) (ft) (°/lOOft) (ft) (ft) (ft) (ft) (ft) 0.00 0.000 0,000 -156.77 0.00 0.00 N 0,00 E 5911950.02 N 460844;75 E 0.00 172.00 0.500 21.000 15.23 172.00 0.70 N 0.27 E 5911950.72 N 460845.02 E 0.291 -0.07 266.00 1.000 33.000 109.22 265.99 1.77 N 0.86 E 5911951.79 N 460845.62 E 0.555 -0.36 388.48 0.800 33,370 231.68 388.45 3.38 N 1.92 E 5911953.39 N 460846.68 E 0.163 -0.95 478.73 1.110 304.280 321.93 478.70 4.40 N 1.54 E 5911954.41 N 460846.31 E 1.505 -0.32 570.09 3.960 288.130 413.19 569.96 5.88 N 2;19 W 5911955.91 N 480842.59 E 3,185 3;67 659.52 5.840 293,250 502.29 659.06 8.64 N 9.31 W 5911958.71 N 460835.49 E 2.156 11.26 749.91 7,740 303.470 592.04 748.81 13.81 N, 18.61 W 59'11963.93 N 460826~21 E 2,483 21.61 838.08 8.830 303.280 679.29 838.06 20.80 N 29.22 W 5911970.97 N 4608,15.64 E 1.237 33.69 928.02 11.190 301.850 767.86 924.63 29.19 N 42.41 W 5911979.43 N 460802.50 E 2.638 48.63 1018.24 14.600 301.690 855.79 1012.56 39.79 N 59.52 W 5911990.12 N 460785.43 E 3.780 67.94 1108.42 17.950 301.770 942.34 1099.11 53.08 N 8'1.01 W 5912003.52 N 460764~01 E 3.715 92.19 1201.17 22.030 301.010 1029.49 1186.26 69.57 N 108.09 W 5912020.15 N 460737.03 E 4.408 122.67 1295.41 25.340 297.820 1115.78 1272.55 88.10 N 141.08 W 5912038.85 N 460704.13 E 3.765 159.39 1388.88 29,070 296.910 1198.89 1355.66 107.72 N 179.03 W 5912058.66 N 460666.28 E 4,015 201.19 1484.15 33,590 297,080 1280.25 1437.02 130.20 N 223.16 W 5912081.37 N 460622.27 E 4.745 249.70 1580.04 38.030 297.910 1358.00 1514.77 156.11 N 272.90 W 5912107.54 N 460572.66 E 4,658 304.54 1673.10 42,820 299.140 1428.82 1585.59 184.95 N 325.89 W 5912136.65 N 46051,9.82 E 5.218 363.27 1767.64 47,710 299.230 1495.34 1652.11 217.69 N 384.50 W 5912169.70 N 460461.38 E 5,173 428.47 1862.41 50.740 297.260 1557.23 1714.00 251.62 N 447.73 W 5912203.96 N 460398.33 E 3.563 498.43 1955.16 52,910 296,530 1614.55 1771.32 284.60 N 512.75 W 5912237.27 N 460333.48 E 2.420 569.87 2047.40 55.750 298.100 1668.33 1825.10 318.99 N 579.31 W 5912272.01 N 460267.10 E 3,375 643.17 2141.16 58.280 295,150 1719.38 1876.15 354.20 N 649.61 W 5912307.58 N 480196.98 E 3,774 720.29 2235.17 61.770 293,510 1766.35' 1923.12 387.73 N 723.81 W 5912341.49 N 460122.96 E 4.008 800.72 2327.76 64,830 292.520 1807.95 1964.72 420.06 N 799.94 W 5912374.21 N 460047.00 E 3.440 882.70 Comment Continued... 22 February, 1999.14:29 .2. DrlllQueet Sperry-Sun Drilling Services Survey Report for 2N-320 Your Ref: API-501032028700 Job No. AKMMgO068, Surveyed: 25 January, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 2422.76 65.920 289.280 1847.54 2004.31 2514.70 67.000 286.180 1884.26 2041.03 2611.97 68.530 284.130 1921.07 2077.84 2703.80 68.870 282.980 1954.43 2111.20 2799.16 68.830 282.330 1988.84 2145.61 2887.84 68.890 282.970 2020.82 2177.59 2982.91 68.550 284.390 2055.33 2212.10 3075.49 68.280 282.400 2089.39 2246.16 3169.38 69.060 283.690 2123.54 2280.31 3187.84 68.950 284.020 2130.16 2286.93 3284.70 68.480 283.080 2165.32 2322.09 3379.01 67.930 281.990 2200.33 2357.10 3475.57 67.750 282.020 2236.76 2393.53 3566.27 67.810 281.770 2271.06 2427.83 3661.91 68.150 283.470 2306.92 2463.69 3756.05 68.020 283.980 2342.05 2498.82 3850.07 67.320 284.070 2377.77 2534.54 3945.70 67.960 283.850 2414.15 2570.92 4036.12 67.990 283.640 2448.06 2604.83 4132.08 68.210 283.960 2483.85 2640.62 4224.94 68.000 284.030 2518.48 2675.25 4320.17 67.450 284.730 2554.58 2711.35 4417.62 67.360 284.050 2592.02 2748.79 4510.02 68.130 283.660 2627.02' 2783.79 4602.22 68.840 285.100 2660.83 2817.60 Local Coordinates Global Coordinates Northings Eastings Northlngs Eastings (ft) (ft) (ft) (ft) 450.85 N 880.60W 5912405.42 N 459966.49 E 476.50 N 980.88W 5912431.49 N 459886.35 E 500.03 N 1047.78W 5912455.47 N 459799.57 E 520.08 N 1130.95W 5912475.95 N .459716.51 E 539.57 N 1217.72W 591'2495.88 N 459629.83 E 557.68 N 1298.43W 5912514.41N 459549.22 E 578.63 N 1384.50W 5912535.80 N 459463.26 E 598.57 N 1468.24W 59!2556.18 N 459379.63 E 618.32 N 1553.44W 5912576.36 N 459294.53 E 622.44N 1570.17W 5912580.58 N .459277.82 E 643.59 N 1657.91W 5912802.18 N 459190.19 E 662.60 N .1743.39W 5912621.63 N 459104.81E 68t.20 N 1830.86W 5912640.68 N 459017.44E 698.50 N 1913.02W 5912658.41N 458935.37 E 717.87 N 1999.54W 5912678.23 N 458848.95 E 738.60 N 2084.38W 5912699.39 N 458764.22 E 759.67N 2168.76W 5912720.90 N 458679.95 E 781.01N 2254.59W 5912742.68 N 458594.23 E 800.92 N 2336.01W 5912763.02'N 458512.92 E 822.16 N 2422.47W 5912784.70 N 458426.56 E 843.00 N 2506.08W 5912805.97N 458343.07E 864.88 N 2591.44 W 5912828.30 N 458257.82 E 887.24 N 2678.~8 W 5912851.11 N 458170.79 E 907.72 N 2761.61 W 5912872.02 N 458087.87 E 929.02 N 2844.70W 5912893.75 N 458004.90 E Alaska State Plane Zone 4 Kuparuk 2N Dogleg Rate (°ll00ft) Vertical Section Comment _ 3.306 3.307 2.506 1.224 0.637 0.677 1.437 2.020 1.526 1.772 1.026 1.221 0.189 0.264 1.686 0.521 0.750 0.702 0.218 0.385 0~237 0.892 0.651 0.920 1.644 968.64 1052.84 1142.87 1228.38 1317.22 1399.84 1488.38 1574.41 1661.80 1679.02 1769.23 1856~69 1945.96 '2029.77 2118.33 2205.63 2292.57 2380.98 2464.77 2553.77 2639.91 2728.02 2817.97 2903.46 2989.22 Continued... 22 February, 1999 - 14:29 - 3- DrlllQueat Sperry-Sun Drilling Services Survey Report for 2N-320 Your Reh AP1-$01032028700 Job No. AKMMgO068, Surveyed: 25 January, 1999 ,0 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 4697.31 67.850 284.960 2695.92 2852.69 4789.70 68.580 285.600 2730.21 2886.98 4881.98 69.500 285.890 2763.22 2919.99 4975.59 69.250 286.510 2796.19 2952.96 5068.66 68.740 287.150 2829.55 2986.32 5162.44 68.340 286.520 2863.86 3020.63 5257.37 67.980 286.870 2899.18 3055.95 5353.55 67.940 286'.500 2935.27 3092.04 5447.62 70.210 285.000 2968.87 3125.64 5542.31 70.060 284.230 3001.04 3157.81 5634.69 70.590 284.010 3032.15 3188.92 5729.12 71.030 284.640 3083.19 3219.96 5823.35 70.930 283.010 3093.90 3250.67 5915.91 71.150 281.650 3123.97 3280.74 6010.51 70.320 280.990 3155.18 3311.95 6103.73 68.530 283.500 3187.95 3344.72 6194.62 67.420 284.050 3222.03 3378.80 6287.82 65.820 283.850 3259.02 3415.79' 6383.38 66.880 283.910 3297.35 3454.12 6476.98 68.670 283.720 3332.75 3489.52 6573.04 68.440 284.130 3367.87 3524.64 6666.54 67.430 284.890 3403.00 3559.77 6760.79 68.210 283.380 3438.58 3595.35 . 6854.04 68.390 282.860 3473.06 3629.83 6954.62 67.950 284.560 3510.46 3667.23 Local Coordinates Global Coordinates Northings Eastings North'lngs East!ngs (ft) (ft) (ft) (ft) 951.94 N 2930.05W 5912917.11N 457919.66 E 974.55 N 3012.81W 5912940.15 N 457837.02 E 997.94 N 3095.75W 5912963.96 N 457754.21E 1022.38 N 3179.88W 5912988.84 N 457670.20 E 1047.53 N 3263.04W 5913014.42 N 457587.17 E 1.072.81N 3346.58W 5913040.13'N 457503.77 E 1098.13 N 3430.98W 5913065.88 N 457419.50 E 1123.72 N 3516.38W 5913091r.92 N 457334.23 E 1147.56 N 3600.94W 5913116.20.N 457249.80 E 1170.03 N 3687.11W 6913139.11N 457163.74 E 1191.25 N 3771.47W 5913160.77 N 457079.49 E 1213.32 N 3857.88W 5913183.28 N 456993.20 E 1234.61N 3944.38W 5913205.02 N 456906.81E 1253.22 N 4029~91W 5913224.08 N 456821.37 E 1270.68 N 41i7.49W 5913241.98 N 456733.89 E 1289.17 N 4202.77W 5913260.92 N 456648.70 E 1309.23 N 4284.60W 59.13281.40N 456566.98 E 1329.86 N 4367.63W 5913302.46 N 456484.06 E 1350.86 N 4452.60W 5913323.89 N 456399.20 E 1371.54 N 4536.74W 5913345.02 N 45631.5.17 E 1393.06 N 4623.52W 5913366.98 N 456228.50 E 1414.77 N 4707.41W 5913389.12 N 456144.73 E 1436.08 N 4792.04W 5913410.87 N 456060.21E 1455.74 N 4876.42W 5913430.97 N 455975.93 E 1477.87 N 4967.12W 59134,53.57 N 455885.34 E Alaska State Plane Zone 4 Kuparuk 2N Dogleg Vertical Rate Section (°/100ft) (ft) Comment 1.050 3077.59 1.019 3163.38 1.039 3249.56 0.675 3337.16 0.844 3424.01 0.757 3511.26 0.511 3599.36 0.359 3688.48 2.836 3776.34 0.781 3865.39 0,616 3952.35 0.784 4041.52 1.639 41'30.57 1.511 4217.97 1.040 4307.05 3.169 4394.18 1.344 4478.40 1.728 4563.92 1.111 4651.42 1.922 4738.03 0.464 4827.41 1.317 4914.05 1.699 5001.30 0.553 5087.88 1.629 5181.20 Continued... 22 February, 1999.14:29 - 4 - DrlllQuest Sperry-Sun Drilling Services Survey Report for 2N-320 Your Ref: AP1.$01032028700 Job No. AKMMgO068, Surveyed: 25 January, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 7046.29 70.630 283.940 3542.88 3699.65 7142.29 69.840 283.320 3575.34 3732.11 7236.34 69.690 284.190 3607.87 3764.64 7329.57 69.360 284.360 3640.48 3797.25 7424.22 69.330 284.470 3673.87 3830.64 7516.65 69.050 284.370 3706.71 3863.48 7611.05 68.780 284.560 3740.67 3897.44 7705.58 70.620 282.740 3773.46 3930.23 7797.97 71.350 282.930 3803.57 3960.34 7891.00 72.230 283.300 3832.64 3989.41 7984.07 71.290 283.230 3861.77 4018154 8077.95 71.070 283.770 3892.05 4048.82 8171.57 70.300 283.890 3923.02 4079.79 8264.76 69.310 282.480 3955.19 4111.96 8356.88 70.330 282.100 3986.97 4143.74 8449.94 69.460 282.170 4018.96 4175.73 8543.24 69.050 282.230 4052~0 4208.77' 8637.05 68.830 282.270 4085.72 4242.49 8731.16 68.230 281.680 4120.16 4276.93 8825.43 68.810 281.090 4154.70 4311.47 8920.08 68.460 281.160 4189.16 4345.93 9013.91 67.840 281.060 4224.08 4380.85 9106.97 67.490 279.900 4259.45 4416.22 9202.82 66.820 279.030 4296.66' 4453.43 9301.62 66.380 280.330 4335.90 4492.67 Local Coordinates Global Coordinates Northings Eastings Northlngs Eastings (ft) (ft) (ft) (ft) 1498.97 N 1520.26 N 1541.24 N 1562.78 N 1584.83 N 1606.34 N 1628.34 N 1649.26 N 1668.66 N 16ee.71N 1709.00 N 1729.74 N 1750.86 N 1770.81N '1789.21N 1807.58 N 1826.02N 1844.60 N 1862.77N 1880.09 N 5050.22W 5913475.10 N 455802.35 E 5138.02W 5913496.84 N 455714.66 E 5223.73W 5913518.27 N 455629.06 E 5308.38W 5913540.24 N 455544.53 E 5394.16W 5913562.73 N 455458.87 E 5477.83W 5915584.68 N 455375.30 E 5563.12W 5913607.12, N 455290.13 E 5649.27W 5913628.48 N 455204.09 E 5734.43W 5913648.33 N 455119.03 E 5820.50W 5913668.82 N 455033.07 E 5906.5'3W 5913689.55 N 454947.14 E 5992.94W 5913710.74 N 454860.84 E , , 6078.73W 5913732.30 N 454775.16 E 6163.88,W 5913752.70 N 454690.12 E 6248.3'6W 5913771.54N 454605.73 E 6333.80W 5913790.35 N 454520139 E 6419,08W 5913809.23'N 454435.21E 6504,63W 5913828.25N 454349.75 E 6590.30W 5913846.86 N 454264~18 E 6676.34W 5913864.63N 4541,78.23 E 1897.09 N 6762.78W 5913882.08 N 454091.87E 1913.87N 6848.24W 5913899.30 N 454006.50 E 1929.53N 6932.88W 5913915.40 N 453921.94E 1944.06 N 7020.01W 5913930.37N 453834.89 E 1959.30 N 7109.39W 5913946.08 N 453745.59 E Alaska State Plane Zone 4 Kuparuk 2N Dogleg Vertical Rate Section (°/lOOft) (fi) Comment 2.991 5266.92 1.023 5357.22 0.882 5445.43 0.393 5532.75 0.113 5621.31 0.319 5707.70 0;342 5795.76 2.655 5884.37 0.814 597!.63 1.019 6059.94 1.013 6,148.27 0.593 6237.08 0.831 6325.40 1.773 6412.79 1.173 6499.13 0.938 6586.38 0.~444 6673.49 o.238 6760.91 0.854 6848.33 0.847 6935.89 0.376 7023.74 0.668 7110.59 1.213 7196.35 1.090 7284.21 1.287 7374.43 Continued... 22 February, 1999 - 14:29 - 5- DrillQuest Sperry-Sun Drilling Services Survey Report for 2N-320 Your Ref: AP1-$01032028700 Job No. AKMMgO068, Surveyed: 25 January, 1999 Prudhoe Bay Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northlngs Eastlngs (ft) (ft) (~t) (ft) (ft) (ft) (ft) 9394.63 65.620 283.100 4373.74 4530.51 1976.55 N 7192.58 W 5913963.75 N 453662.49 E 9487.77 64.850 282.440 4412.75 4569.52 1995.24 N 7275.06 W 5913982.88 N 453580.11 E 9582.36 63.960 282.350 4453.62 4610.39 2013.55 N 7358.38 W 5914001.62 N 453496.89 ,E 9676.58 64.090 284.670 4494.89 4651.66 2033.34 N ,7440.73 W 5914021.83 N 453414.64 E 9769.08 63.520 285.580 4535.72 4692.49 2055.00 N 7520.85 W 5914043.90 N 453334.63 E 9863.41 62.880 284.700 4578.25 4735.02 2076.99 N 7602.12 W 5914066.31 N 453253.47 E 9958.54 61.290 284.950 4622.79 4779.56 2098.49 N 7683.39 W 5914088.24 N 453172.32 E 10051.32 60.230 283.940 4668.11 4824.88 211'8.69 N 77.61.78 W 5914108.84 N 453094.04' E 10141.00 58.430 285.750 4713.85 4870.62 2138.44 N 7836.34 W 591:4128198 ,N 453019.58 E 10235.23 57.070 284.400 4764.14 4920.9i 2159.,17 N 7913.28 W 591'4150.11 N 452942.75 E 10329.76 56.550 284.670 4815.88 4972.65 2179.03 N 7989.86 W 5914170.36 N 452866.27 E 10424.08 56.890 283.980 4867.64 5024.41 2198.54 N 8066.26 W 5914!90.26 N 452789.98 E 10518.15 56.610 283.810 4919.22 5075.99 2217.43 N 8142.62 W 5914209.55 N 452713.71 E 10611.99 56.220 282.690 49'71.13 5127.90 2235.35 N 8218.71 W 5914227.86 N 452637.71 E 10707.23 55.670 283.740 5024.46 5181.23 2253.38 N 8295.53 W 5914246.29 N 452560.99 E -10800.06 55.430 282.790 5076.98 5233.75 2270.95 N 8370.04 W 5914264.24 N 452486.58 E ~10896.13 55.340 282.680 5131.55 5288.32 2288.38 N 8447.15 W 5914282.07 N 452409.55 E 10989.75 54.310 282.450 5185.48 5342.25 2305.02 N 8521'.85 W 5914299.10 N 452334.94 E 11061.00 54.310 282.450 5227.05 5383.82 2317.50 N 8578.35 W 5914311.87 N 452278.50 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.717° (25-Jan-99) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 285.380° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11061.00ft., The Bottom Hole Displacement is 8885.88ft., in the Direction of 285.118° (True). North. Alaska State Plane Zone 4 Kuparuk 2N Dogleg Rate (o/!ooft) Vertical Section (ft) Comment 2.841 1.048 0.945 2.218 1.077 1.074 1.687 1.486 2.654 1.884 o.60o 0.710 0.334 1.078 1.081 0.883 0.133 1.118 0.000 7459.22 7543.,70 7628.89 7713.54 7796.54 7880.74 7964.79 8045.73 8122.86 '8202.55 8281.65 8360.48 8439.13 8517.24 8596.09 8672.59 8751.57 8828.00 8885.79 Projected Survey Continued... DrlllQueet 22 F~bruary, 1999 - 14:29 - 6. Sperry-Sun Drilling Services Survey Report' for 2N-320 Your Reft AP1.501032028700 Job No. AKMM90068, Surveyed: 25 January, 1999 Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 2N i~ Comments Measured Depth (ft) 11061.00 Station Coordinates TVD Northlngs Eaatinga (ft) (ft) (~t) 5383.82 2317.50 N 8578.35 W Comment Projected Survey 22 February, 1999- 14:29 .7. DrlllQueet MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission Robert Christenson~ DATE: January 31, 1999 Chairman THRU: Blair Wondzell, ~ P. I. Supervisor ~(~ FROM: Chuck Scheve, ~ c~ SUBJECT: Petroleum Inspector FILE NO: ab5ka5ge, doc BOPE Test Pool 6 Tarn 2N-230 PTD # 99-001 Sunday, JanuarY 31; 1999: I traveled to Arco's 2N-230 well being drilled by Pool Rig 6and witnessed the initial BOPE test on this well. As the attached AOGCC BOPE test report shows, the test lasted 9 hours with 3 failures. The lower pipe rams door seal failed on the initial pressure test; this seal were repla ~ced and tested O1~ The casing pressure gauge and one of the position indicaters on the remote choke panel were not operating properly at the time of this test, but will be repaired before drilling below surface casing. The testing went well_with the exception ofthe above mentioned failures. The rig was clean and all related _equipment appeared to be in good working order. The location though crowded was well organized allowing good access to the rig. Summary: I witnessed the initial BoPE test on Pool Rig 6 drilling Arco's 2N-230 Well: Pool 6, 1131199, Test time 9hours, 3 failures Attachment: ab5ka5ge.xls X Unclassified Confidential (UnclaSsified if doc. removed ) Confidential STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg Contractor: Operator: Well Name: Casing Size: Test: Drlg: X Workover: ~ DATE: 1/31199 Pool Rig No. 6 PTD # 99-001 Rig Ph.# 659/7562 ARCO Rep.: Burle¥ I Overstreet 2N-230 Rig Rep.: Broach I Barr 7 518 Set ~ 3253 Location: Sec. 3 T. Initial X Weekly Other 10N R. 7E Meridian UM Well Sign OK Dd. ~g OK Hazard Sec. OK FLOOR SAFETY VALVES: Quan. Upper Kelly ! IBOP 1 Lower Kelly I IBOP 1 1 MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gert) PTD On Location YES Standing Order Posted YES Ball Type Inside BOP I Test Pressure 250/5000 250150O0 25015000 25015O00 P/F BOP STACK: Annular Preventer Pipe Rams 1 Lower Pipe Rams 1 Blind Rams 1 Choke Ln. Valves HCR Valves 2 Kill Une Valves 1 Check Valve Quan. Test Press. P/F I 250/2500 P P 25013500 25o/3soo 250/3500 I 250/35O0 25O/350O 250/3500 N/A MUD SYSTEM: Visual Alarm Trip Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK Meth Gas Detector OK OK H2S Gas Detector OK OK CHOKE MANIFOLD: No. Valves 15 No. Flanges 30 Manual Chokes 1 , Hydraulic Chokes 2 Test Pressure P/F 2so/sooq Functioned Functioned ~ P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure__..._ System Pressure Attained Blind Switch Covers: Master: Nitgn. Bt's: 29OO 1400 minutes 25' sec. 2 minutes 35 sec. OK Remote: OK 6 soo Psi Psig. ·: ..... -'... .:. - . .* .............. . ............ .- ............ Number of Failures: 3 ,Test TIme: 9.0 Hburs. NUmberof valves tested 23 Repair or Replacement of Failed Equipment will be made within 0 days:~lotify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not rotumed by theinspector _within 12 hours please COntact the P. I. Supewisor at 279-1433 REMARKS: Casing press.u~regaU~le on remotecbpke pa,~el not worldn>q '/ Choke position indicater not a;Utat~-onone-of the remotly operated chokes" Door seal on iowerpipe r~ms failed on_ initialtest v Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c - Inspector F1-021L (Rev.1?J94) S~TE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Chuck Scheve TONY KNOWLES, GOVERNOR CONSERYATIO V C SiON 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE (907) 279-1433 FAX (907) 276-7542 January. 14. 1999 Paul Ms~.~-olini, Drilling Team Leader ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 2N-320 ARCO Alaska, Inc. Permit No: 99-01 Sur Loc: 57!FNL,-748'FEL, SeC,-3,rT9N, RTE~ UM Btmholo Loc. 2297'FSL, 1210'FWL, Sec.-33, TION, R7E, UM Dear Mr. Mazzolini: Enclosed is the approved application for permitto drill thc above rcfcrenccd well. Annular disposal of drilling wastes will not be approv~ forTthis well until sufficient data is submitted to ensure that-the requirements-of20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent 6n:obiaining a Well cementcdsurfaCc Casing confirmed by a valid Formation Integrity' Test (FIT).- Cemcdting records, FIT da~, and _an3' CQLs must be submitted to the Commission on form 10-403 prior to the staRofdisposal operations. Annular disposal has not boca requested as_ part of the Permit to Drill application for Kuparuk River unit Weil No. 2N~320. pleasenote that any disposal of fluids gcnerat:c~ from tiffs drilling operation which arc pumped down the surface/pr_eduction casing annulus Of a well approved for annular disposal on Drill Site 2N must comply with thc rcquircmcnts and limitations Of 20 AAC 25.080. Approval Of this permit to drill doesnot authorize disposal of drilling x~-aste in a volume greater-than 35,000 barrels through the annular spa/:6_of a single well or tO usc that well for disposal purposes for a period longer than one year. The permit to drill does not exempt you from obtaining~additional permits required by law from other g0vcrnmental_agen~jeS, and does no/authorize condUcting drilling operations until all other required permitting determinations arc made. Blowout prevention equipment (BOPE) mustbe tcstcdin accordance with 20 AAc 25 035. SuffiCient notice (approximately 24 hours) must be givcntoallow a rcpresentative of the Commission t~ witness a test of BoPE installed priOr to drilling new hole Notice may be given by Contacting the Commission pctrolcum fiel~dmspcctor on thc North Sl0pe pager at 659-3607. Sin ~ / ~ , Chairman By ORDER OF THE COMMISSION dlf/En¢losures cc: Department of F~sh & Game, ! labitai SeCtion w/o ehui Department or' Environmental Conservation vdo cncl_ A -~?KA OIL STATE OF ALASKA ~ AND GAS CONSERVATION COM~SION PERMIT TO DRILL 20 AA• 25.005 ~-'- I ..... Development la Type of Work ~ - Rednll lb Type of Well Exploratory StratEgraphlc Test Re-Entry Deepen, 'I Service Development Gas ~i~~,~F~ Multiple Zone 2 Name of Operator ~ 5 Datum Elevation (DF or KB) 10 Field and Pool ARCO Alaska, Inc. RKB 38', Pad 120' feet _ Kuparuk River Field 3 Address 6 Property Designation P: O. Box 100360, Anchorage, AK 99510-0360 ADL 380054~ ALK 4602 4 Location of well at surface ' 7. Un,t or propbrty Name 11 Type Bond (see 20 AA• 25 025) 57' FNL, 748' FEL, Sec. 3, T9N, R7E, UM ~ Statewide At top of productive ~nterval (@ TARGET ) 8 ~ Well number Number 2182' FSL, 1672' FWL, Sec. 33, T10N, R7E, UM i[~~ #U-630610 At total depth 9 Approximate spud date Amount 2297' FSL, 1210' FWL, Sec. 33, T10N, R7,E, UM 1/15/99 $200,000 12 Distance tO nearest 13 D~stance t6 nearest well 14. Number of acres in property 15 Proposed depth (MD and TV•) property I,ne 2N-319 ~ 11084' MD 1210' @ TD feet 11.1 @ 51'1' feet 2560 5373' TVD feet 16 To be completed for dewated wells 17 Anticipated pressure0 AAC 25 035(e)(2)) K~ckoff depth 500' feet Maximum hole an, gle 69.07° Max]mum surface ps~g At total depth ('I~D) ~{~)_-~ ps~g 18 Casing program Setting Depth size Speclflcal,ons Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld ! 80' 38' 38' 118' 118' :~.2.00 CF 9.875" ~7~.e~2~,~ r2-9~'7~ RL'~8~ 'B~I~C~I~OE 3212' 38' 38' 3250! 2300' 360 SX Arcticset III & ' 235 Sx Class G 6.75" ~.--6~ ~-~ ~8e"~ ~TC-M i 10136' 38' 38' 10174' 4851' 360 sx Class G 6.75" ~ ~ '[F..~ '~-~0~ 8rd EUE 910' 10_174' 4851' 11084' 5373' (included above) 19 To be completed for Rednll, Re-entry, and Deepen Operations Present well condition summary Total depth measured feet Plugs (measured) true verbcal feet Effectwe depth measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Sct°r~nc~t~ r~°lrRECEIVED Surface Intermediate L~rn°edrUCti°n;0 R IGINAL Perforation depth measured true vert,cal ~ O~ & ~1~ ,C~, O~ 20 Attachments Fd~ng fee X Property plat [~ BOP Sketch X Dwerter Sket~"r~;;-~"-'~-~ Dnlhng program X Dnlhng fluid program X Time vs depth plot [--j Refraction analysis r-] Seabed report C] 20 AAC 25 050 requirements X 21 I hereby certify that the foregoing ~s true and cg, Fect to ~e best of my knowledge S,gne~_~ jf~~ ~'~.~~.~ ~il~-/,)Izi4.; T,tle Tarn Drilling Team Leader. Date //~/~ ..... -'~r.~ -- v~/- - ' - - Comm~lon Use Only ' PermltNumber /l~APInumber .... I Approvaldate ~, t x,(. /~../~ ~ See cover letter for 5~5~.~ / I 5o.~O~ ~O~ :~ I /'~ /'~"-"'7'~ I°therrequ'rements C;n~,hons~f-approval ~ ' Samples required ~ Yes ~ No Mud logrequlred D Yes ~ No Hydrogen sulfide measures [] Yes ~ No D,rect,onal survey reqmred ~ Yes ~ No Requ,redwork,ngpressureforBOPE E~] 2u r~ (~ [-I 5u I'-I 1OM ~ 15U ~her' order of ORIGINAL SIGNED BYComm,ssioner thebY commission Date Approved by Rnh~_~ M ~_h.-.'=; ........................ Form 10-401 Rev 7-24-89 & uJ~,lc)n Submit in tnphcate , . . . . . 11. 12. 13. ARCO Alaska, Inc. GENERAL'I3RILLING AND COMPLETION PR~EDURE KUPARUK-RIVER FIELD - PRODUCER KRU 2N 320 = Move in and rig up Pool #6. Install diverter system. Drill 9.875" hole to 7-5/8" surface casing point according to directional plan. Run and cement 7-5/8" 29.7#, L-80 BTC-Mod casing string to surface. Employ lightweight_permafrOSt cement lead slurry to assure cement returns to rthe surface. AdeqUate excess cement will be pumped to ensure cement reaches the surface during the firs{ stage cement job. NOTE: TAM Port Collar will be placed in the 7-5/~" Casing __+! 000' TVD below the surface. Port collarwill onlybe opened,and used if cement does not circulate to surface. As an alternative, if lobservations at surface indicate Cementt(~p is above the Port-Collar, a top ]'ob may be performed in lieu of Utilizi_ng theport Collar. A Top Job may Only be performed after consulting withthe AOGCC. T..hisiS based On the cement thickening time and time required to trip in, the hOle and open the Port Collar to_perform the-second stage cement job. see attached TAM Port Collar Utilization Decision Tree. Install and test BOPE to 3 50~i: Test casing to; 2~000 psi. Drill out cement and 20' of new hole.- Perform formation integrity test not to exceed 16.0 ppg EMVV. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). . Drill 6-3/4" hole to TD according to directional plan. Run LWD logging equipment with density and porosity tools. Note: If significant hydr°carbon~zones arepresent above the Tarn, su--Effr~ent cementwill be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(C). Run and cement 5-1/2" L-80 LTC Csg X 3-1/2" L-80 8rd EUE-Mod tapered production caSing string with ~Baker casin§ seal receptacle at crossover point. Pressure test casing to 3~500 psi. Run 3;1/2" L80 8rd EUE-Mod completion asseml~ly./Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3,500 psi. ND BOPE and install production tree. Secure well. Rig down and move out. Hydrocarbon intervals will be tested after the rig move. DRILLIN(~UID ARCO Alaska, Inc. ~ PROGRAM, PRESSURE :CA"~UI~TIONS, AND DRILLING AREA RISKS Well KRU 2N 320 Drilling Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to surface casing point 9.0-10.2 ppg 15-35 25-50 70-120' 10-25 15-40 5-7 9.5-10 +10% Drill out to TD 8.5- 10.0 ppg 12-24 15-30 45-60 2-6 4-8 4-6 through Tarn 9.0-10 <11% Drilling Fluid System: Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Degasser Pit Level Indicator (visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure (MASP) while drilling the production hole is calculated using a surface caSing leak-off of 13.5 ppg EMW(0.70 psi/fi) and a gas gradient of 0.11 psi/ft. ~This shows that formation breakdown would occur at a surface pressure of 1,357 p. Si, Therefore ARCO will test the BOP equipment to 3,500 psi after setting surface casing. MASP = (2,300 ft)(0.70 - 0.11) = 1,357 psi Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2N pad are expected to be ~2,350~psi (0.50 psi/fi). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a~required mud weight of 9.5 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 5,100'. Well Proximity Risks: The nearest well to 2N-320 is 2N-319. The wells are i 1.1' from each other at a depth of 511' Risks~ ARCO Alaska, Inc. {~ Drilling Area The primary risk in ther2N-320 drilling area is shallow gas below the permafrost. Therefore the surface hole will need to be drilled with weighted mud (9.8- 10.2 ppg) to avoid underbalancing the hole. Another observed problem in the area is lost circulation at around 3,300' TVD and in the Tarn formation. Analysis of pressure data from offset wells shows that a mud weight of 9.6-10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well. The 9-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. Annular Pumping Operations: Incidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class II disposal well. (Note thatcement rinseate will not be injected down the dedicated disposal well but will be recycled Or held for an Open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut doWn (> 4 hr) in pumpingoperations. The 2N-320 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. We ~,~~t~- ' ~' ~0~§~-~e~iff~-d~-~r~- n~h~l~tfi~in~{Sf-~fi~ids~0t;curring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water_wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set'in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales arepart of the Colville Group and are knoWn to provide vertical-barriers to fluid flow. The surface casing shoe will be set a minimum of 200' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids-to'be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission ofthe AOGCC. Fluid densities will range from diesel to a maximum of 12.0 pp.g for_drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping Pressure of 1;500 psi for annular injection, the maximum presSure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0;052) * (Surf: Shoe TVD) + 1,500 psi - (12.0 ppg) * (0.052) * (2,300') + 1,500 psi Max Pressure = 2,935 psi This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annularpumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf)Grade Range Type Collapse Collapse Burst Burst 7-5/8"29.7 L-80 3 BTC 4,790 psi 4,072 psi 6,450 psi 5,483 psi 5%" 15.5 L-80 3 LTC-Mod 4;990 psi 4,242Psi 7,000 psi 5,950 psi ARCO Alaska, Inc. (~) I 3~" I 9.3 I L-80 I'"" 2 18rd EUE Mod110,530 psiI 8,~,b.~ psi 11o,16o psiI 8,636 Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). ARCO Alaska, Inc. Pool #6 13-518" 5,000 PSI BOP COMPONENTS 3" 5,000 psi wP MANUAL GATE VALVE ~ KILL LINE 3" 5,000 psi wP GATE VALVE w/hydraulic actuator Adaptor Spool 13-5/8" 5,000 psi WP x 11" 5,000 psi WP 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w! companion flange to bell nipple ] 4" 5,000 psi WP GATE VALVE w/hydraulic actuator 1CHOKE LINE DOUBLE 13-5/8" 5,000 psi WP, HYDRIL BOP w/pipe rams on top and blind rams on bottom 13-5/8" 5,000 psi WP DRILLING SPOOL wi one 3" 5M psi WP outlet and one 4" 5M psi WP outlet l SINGLE 13-5!8" 5,000 psi WP, HYDRIL BOP w/pipe rams TJB 1/8/99 ARCO Alaska, Inc. Diverter Schematic Pool #6 21%" 2,000 ,psi WP DRILLING SPOOL w/16" Outlet Flowline 21%" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 300 psi WP HYDRAULIC KNIFE VALVE 16" OD DIVERTER LINE 16" 62~ppf PEB coNDUCTOR PIPE set at 80' (GL) ' TJB 1/8/99 ARCO Alaska, Xnc. Tarn Drill Site 2N 320 slot #320 Tarn Develolment Field North Slope, Alaska SUMMARY CLEARANCE REPORT 32TCLUD22T~ pOSTTTON UNCERTA~HT'rES Baker Hughes :I:HTBQ Your re£ : 320 Version #6 Our re£ ; prop3254 License ; Date printed : 30-Dec-98 Date created : 22-Dec-98 Last revised : 30-Dec-98 FieZd is centred on n70 12 49.742,w150 18 33.414 Structure is centred on nT0 10 13.955,w150 18 32.772 Slot location is nT0 10 13.393,w150 18 54.452 Slot Grid coordinates are N 5911950.023, E 460844.753 Slot local coordinates are 57.10 S 748.36 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Prox4--4ties will incorporate e11ipsee - when survey tools are defined for both wells. Ellipse separation in reverse brackets, e.g. )10.2(, where available. o~]ect wellpath pNSS <0-9134'>,,313,Tarn Drill Site 2N PM~S <0-7431'>,,345,TarnDri11 ~ite 2N PMSS <0-10655t>,,337,Tarn Drill Site 2N <?090-10245i>,,337A, Tarn Drill Site 2N PMSS <0-11197'>,,315,Tarn Drill Site 2N PMSS <0-12339f>,,341,TarnDri11 Site 2N <10920 - 1122St~,,331,Ta~Dr~11 Site 2N P~S ~9483 - 9631s~,,3%3,Ta~ Dr~11 Site 2N - P~S ~0-12077e~,,335,Ta~ Drill Si~e 2N P~S ~808S-8239t),,339,Ta~Dr~11 Site 2N ~S ~0-7039t~,,319,Ta~ Dr~11 Site 2N ~S ~0-8500s~,,317,Ta~Dr~11 Site 2N P~S <0-95~3~),,323,Ta~ Drill Site 2N P~S ~S303 - 11S26o),,321,Ta~Dr~11 Site 2N p~ ~0-917S~),,32~,Ta~ Dr~11 S~te 2N ~923S - 10028~),,32~,Ta~ Dr~11 Site 2N P~S ~7387 - 8182'~,,325,Ta~ Dr~11 Site 2N ~S ~0-9690s~,,329, Ta~Dr~11 Site 2N P~S ( 22S0 - 7162*>,,34, T~ 93 Ta~ 91 (Htra~gh~ Hole),,1,T~ 91 P~S ~0-7650*),,Ta~92,T~ 92 Closest approach w~th 3-D MinimumDistance method Last revised Distance M.D. Diverging £r~nM.D. 4-Aug-98 )91.8( 633.3 8240.0 21-Jul-98 )373.6( 400.0 555.6 18-Ju~-98 )252.8( 300.0 10720.0 29-Jul-98 )252.8( 300.0 10200.0 30-Sep-98 )59.6( 622.2 10900.0 30-Sep-98 )315.0( 100.0 10860.0 9-Oct-98 )164.1( 200.0 10940.0 9-Oct-98 )342.4( 300.0 300.0 27-Oct-98 )156.7( 1215.0 11060.0 9-0ct-98 )279.4( 400.0 9562.0 9-Oct-98 )11.1( 511.1 511.1 14-Aug-98 )42.3( 511.1 6880.0 23-Jul-98 )44.7( 200.0 8480.0 21-Dec-98 )15.0( 100.0 10860.0 21-Dec-98 )15.0( 100.0 11020.0 21-Dec-98 )15.0( 100.0 11020.0 21-Dec-98 )31.9( 1283.8 1283.8 28-May-98 )71.4( 4720.0 7420.0 13-Nov-98 )6608.0( 533.3 533.3 13-Jul-98 )3400.3( 3800.0 9600.0 12-Au9-97 7390.2 11083.5 11083.5 7-Dec-98 )12757.1 2140.0 3500.0 Created by rlxse FOE~: BRA~$FIELD Dot~ plottetl · 29-D~c-9~ Plot Reference Is 320 Vmrelan ~$ , Coordinates are in feet reference slot ~1320 True Vertical Depth-, ore reference RKB (Pool II6) 500 lOOO 1500 2000 2500 5000 3500 4000 45OO 5000 5500 ARCO Alaska, Inc. Structure: Tarn Drlll Site 2N Well : 320 Field : Tam Development Field Looaflon: North Slope, Alaska <- West (feet) I 2297' FSL, 1210' FWL I SEC 3.:3, TI ON, R7E I ~RKB ELEVATION 158' 9000 8500 8000 7500 7000 6500 6000 5500 5000 4500 4000 .3500 3000 2500 2000 1500 1000 500 0 TD LOCATION: ,~o(,~e~. TARGET LOCATION: 2182' FSL. 1672' FWL 2500 ~' SEC 53, TION, R7E TVD=5040 TMD= 10503 DEP=8442 2000 NORTH 2259 ~(3 WEST 8140 ~.oo KOP TVD=500 TMD=§O0 DEP=O ;3.00 .. 16.00 BEGIN 4 DEG/IO0' BUILD TVD=994 TMD=IO00 DEP=65 4.00 B/ PERMAFROST TVD= 1208 TMD= 1227 DEP= 136 32 O0 T/ WEST SAK SNDS TVD=1252 TMD=1276 DEP=156 48,00 BEG,N TURN TO TARGET ;V~=~721 T.0=1875 DEP=5~I (TO TARGET) ~ EOC ~D=2018 TMD=2462 DEP=IO09 __~-- , ?e~-;, 5o~' / ~/8" CASING PT WD=2300 TM0=3250 DEP=1745 ~C80 W0=2470 TMD=5726 DEP=21go SURFACE LOCATION' ~- 57' FNL. 748' FEL' MAXIMUM AN~LE 00.07 DEG C40 ~D=3883 TMD=7681 DEP=5883 '4~6 48 DLS: 2.00 dog per 100 ft C35 WD=5201 TMD=10784 DEP=8672 TD - CASING PT WD=5573 TMD=11084 DEP=8918~ 1500 1000 ~-~ 500 v 6000 , , , , i i 0 500 1000 I I I I I I I I I I I I I II I II I I I I I I I I I I I I I I I 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 go00 9500 VerticalSection (feet)-> Azirnufh 285.58 wlfh reference 0.00 N, 0.00 E from slot #520 ^ I ARCO Alaska, Inc. Structure: Torn Drill Site 2N 220 200 Well: 520 Field: Tom Developmenf Reid Loooflon: Norfh Slope, Aloako <- West (feet) 340 520 300 280 260 240 220 200 180 160 140 120 100 80 60 40 20 0 20 40 60 80 180 ~ 160 140 120 100 ,~. 80 v 1700 1500 1100 ~%2~00 1500 900 ~ ~ ~ 1~00 ~ %1~ ~ ~ ~ ~ ~ ~ ~ 700 11oo -~ ~700 O0 ~'-_~oo 300 *'" 1500 ~ ~.1300 900 -~ ~. 1700 '~ "' -,~ 1300 ,~. 11 O0 \ \\ \\\~\1300 2100 ~1300 '~00 ~ 1900 ~ ,°° 1500 900 50~ 500 500 1300 500'~' 220 2OO 'E: 6o 0 Z 2O 20 4O 8O 180 140 120 0 20 0 m m i i m ~ m i i i i i i i i i i i i i i i i i I i i 300 280 260 240 220 200 1~0 1~i0 140 120 100 8'0 6'0 4'0 2'0 $ 2'0 4'0 6'0 <- West (feet) 2O Cr~ot~d by rix~ FOR: BRA~ISFIELD Dote plotl~: 30-Deo-g8 Plot I~femn~ b 320 V~on ~5. 1120 640 IARCO Alaska, Inc. Structure; Torn Drill SHe 2N Well: 320 Field: Tarn Development Reid LooGilon: North Slope, AlaBko 600 560 520 48O <- West (feet) 640 600 580 520 080 1040 1000 960 920 880 840 800 760 720 680 640 600 560 520 490 440 400 360 320 280 240 I I I I I I i I I I I I I I I I I I I I i i I I I I I I I I I I I I I I I I I I I I ,, , -------''~~ X %500 ',, 210~' ~ '~0 ',2700 1 ) o ~ X ", ' ' --~300 15~, ~2400 X , 200~~ ~ ~ ~ ~ ~ ~ 1400 -'---.,~oo"--~ ,.~-. ~ ~ ~ ~ ~1600 ~ 120 ...... 1600 ~ ~ ~ ~ ~.~ 5~ 4~0 C A 440 440 A I I ~ Z "~ 400 .400 Q.1 .1~ 360 360 Z 320 280 24O 320 240 2OO 200 160 160 120 120 1120 1080 1040 1000 960 920 880 840 800 760 720 680 640 600 560 520 480 440 400 560 320 280 240 <- West (feet) C Cr.ot.d by m.. FOR: BRA~$FIELD Dote plott~: Plot ~ler~ce b ~ V~on ~5. ~lnat~ om r~ ~rtl~l ~pt~ are mfer~ R~ (~1 ~6), ARCO Alaska, Inc. Sfruoture: Torn Drill Site 2N Well: 320 Field: Tam Development Fleld Loootlon: North Slope, Alaeka <- West (feet) 2900 2800 2700 2600 2500 2400 2300 2200 2100 2000 1900 1800 1700 1800 1500 1400 1300 1200 1100 t000 900 800 1200 11oo 10oo 900 800 A 700 I 500 5OO 0 Z 400 300 200 100 100 2400 3600 ~oo '" ~ '" ~.... -.. "' 3400 ~- ~' 3200 ~' ~. ,..2400 ~~.~~600 2400 ~ ............2000 2200 ! 2200 ~800 2000 3600 !000 4000~' ~, \ \ 2600 3800~ 360~ 1800 1200 1100 ,ooo C,i 900 3200 800 I i i i i i I I I I I I I I I I I II I I I I I I I I I I I I I I I I I II I 2900 2800 2700 2600 2500 2400 2300 2200 2100 2000 1900 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 800 <- West (feet) 200 100 100 2600 2400 2200 2000 1800 ,/~ 1600 ~ 1400 1200 t- O Z 1000 BO0 6O0 400 200 IARCO Alaska, Inc. Sfruofure: Torn Drill Site 2N Well: $20 Field: Tom Development Iqeld Loooflon: North Slope, AIosko <- West (feet) 6200 6000 5800 5600 5400 5200 5000 4800 4600 4400 4200 4000 3800 3600 3400 3200 3000 2800 2600 2400 2200 2000 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I i [~,~600 2200 - ~ .340~0 [..~400 .... "' --... "--- ... ' 5200 0 1800 "-,..~600--, ~ -. -. , ~000 ]000 ""~2~6°° ~600 "-- -, ~600 - --, ' -, ~ 6~,0 28oo '-,,..~ .oo -_. -....oo - ~400 '-.- ....-. ~ -. """ ~""~.'-~ ~3000 ~ ~. 3200 "' '"~-..~,.... "~ -. 3800 .oo ~ -. 800 4200 '" "~'"'"""~ 4000 ~ 3800 2800 ~ - 600 5600 1200 ~ 1000 ~ 5600 2400 5400 ........... 2600---"' ~ 3000 .... -- ....... 2~200 2600 5400 3200 3000 2800 ------ -- ........... ~0.~0 ' , , 2600 · -*-- 2400 a 400 200 6200 6000 5800 5600 5400 5200 5(XX) 4800 4600 4400 4200 4000 5800 .t600 .1400 .1200 .1000 2600 2600 2400 2200 2000 <- West (feet) Created by rlxll FOR: BRA~SFIELD Dote plo~tod: Plot Rofereflco Is 320 V~lrOfl J6. Coordifloteo om In feet referonao .Jot #320. True VerUcol (~pths orl referorme RKB (Pool diG), INTI~ ARCO Alaska, Inc. Structure: Tarn Drill Silo 2N Well: 320 Field: Tarn Development Reid Loooflon: North Slope, Alaska <- West (feet) 9400 9200 9000 8800 8600 8400 8200 8000 7800 7600 7400 7200 7000 6800 8600 6400 6200 ~ 5800 5~00 5400 5200 5000 3400 t t t s ; t I t t I I ~ t ~ t t i s t I I I I I I I I I I I I I I I I I I I I I I I I 3200 3000 28OO 2600 2400 2200, 2000 18oo 1 GOO 1400 ~' ~ .~. 4400 '% ,..4200 , '~ ~....5000 ~' ~ 4800 ~ ~ ~ ~ ~ 4500 ~ ~000 ~ 4400 ~ ~ ~ ~ ~ ~800 -- .48..00.. -. 1200 1000 ~4 800 3400 3200 3000 - 2800 2600 2400 2200 2000 1800 1600 1400 1200 IOO0 ~0 5200 ~ 5000 4800 4600 '"""'--~"-~- 800 i 800 ~ BOO , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , BOO 9400 9200 9000 8800 8600 8400 8200 8000 7800 7600 7400 7200 7000 6BIX) 5600 5400 6200 5CXX} 8BOO 5600 5400 5200 5000 <- West (feet) 0 Alaska, Structure: Tarn Drill Site 2N Well: 320 field : Tarn Development Field Looation: North Slope, Alaska WELL PROFILE DATA 510 290 520 330 34O 350 280 27O TRUE NORTH 0 10 20 30 40 50 60 70 8O 9O 1500 100 250 240 110 1500 230 22O 210 200 190 180 Normal Plane Travelling Cylinder- Feet 2100 2~00 140 150 160 170 All depths shown are Measured depths on Reference Well ARCO Alaska, Inc. Post Office Box 100360L~ Anchorage, Alaska 9951~0360 January 8, 1999 Robert Christenson, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit toDrill KRU 2N-320 Surface Location: 57' FNL 748'*FEL Sec 3 T9N R7E, UM Target Location: 2182' FSL, 1672' FWL Sec. 33, TION~ RTE, UM Bottom Hole Location: 2297' FSL, 1210' FWL Sec. 33, T10N, RTE, UM Dear Commissioner Christenson, ARCO Alaska, Inc.r hereby files this Application for Permit to Drill a development well in the Tarn_area, KRU 2N-320, located_approximately seven miles Southwest of the Kuparuk River Unit's 2M Drillsite. The well is accessed via a new gravel road-originating at 2M Pad. Pool #6 will drill the well. If commercial, the Well will completed with Pool #6 also. Attached is the information required by 20 AAC 25.005(c). There will be-no reserve pit for this Well. Waste drilling mud will be disposed of down the annulus of an existingwell on Drillsite 2N(subject to AOGCC approval), or hauled to-a'KRU ClaSs II disposal well. All cuttings generated will be either stored ~temp0rarily onSite or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. The TD of this well will be in the Tarn formation. H2S has not been encountered in this region:in any stratum shallower than the Lisburne Formation. Therefore, ARCO has not included an H2S contingency plan with this Application, and requests_an exemption ;from the H2S requirements. However, ail drillingmud~ cores and produced fluids exiting the wellbore will be monitored for detectable levelS of H2S. The following are ARCO's designated contacts for reporting responsibilities to the Commission' 1) Completion Report (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 2) Geologic Data and Logs DOug Hastings, Geologist (20 AAC 25.O71) RECEIVED 265-6967 AP. CO Alaska, inc. is I Subsidim'y of Aliaalicl~chfield(~ompauy JAN G8 1999 & Gas Cons. David W. John~--3 Application for I~it to Drill Page 2 KRU 2N-320 (~ If you have questions or require additional information, please contact Tom Brassfleld at 265-6377 or me at 263-4603 in our AnchOrage office. Sincerely, Paul Mazz61ini Drilling Team Leader Exploration / Tarn Development Group Attachments cc: KRU 2N-320 Well File ARCO Alaska, Inc. AAI PAYABLES P.O. Box 102776 Anchorage, AK 99510-2776 PAY TO THE ORDER OF: CHECK NUMBER 2O5O8738O 839 ALASKA DEPT OF REVENUE ALASKA OIL, & GAS CONSERVATION COMMI 3001 PORCUPINE DRIVE DECEMBER 22, 1998 VOID AFTER 90 DAYS 0997579 Chioago, IIIinola Payable Through Republic Bank TRACE NUMBER: 205087380 "' ;0 qOP. ? Oqq? ADMINISTRATION 1 Pe111111 fee attached 2 I ease number appropriate 3 Umque well name and nt,nlbe~ 4 Well Iocaled in a delined pool 5 Well Iocaled proper distance fronl drilhng uml boundmy 6 Well located proper distance from other wells 7 Sufflc~enl acreage available in drilling 8 If devlaled, is wellbore plat included 9 Operator only affected party 10 Operator has appropriate bond in force . 11 Permit can be issued without conservation order ~1~ ~,~~ 12 Pern,t can be issued wilhout administrative approval ., 13 Can permit' be approved before 15-day wait ENGINEERING 14 15 16 17 k~o ~8 19 o 20 ~,~ 21 22 23 24 25 APPR DA1 E 26 ~ ~U..['~ ~' 27 28 29 ...... GEOLOGY 30 31 32 33 I.~ [~A TE 34 ~N~LX~ blSPOSAL 55 Conductor string provided Surface casing protects all known L~SDWs CMT vol adequate to circulate on conductor & surf csg CM 1 vol adequate to tie-in long string to surf csg CM r will cover all known productive horizons Casing designs adequate for C, T, B & permafrost Adequate tankage or reserve pit. . If a re-drill, has a 10-403 for abandonment been approved Adequate wellbore separation proposed If diverter required, does it meet regulations Drdiing fluid program schematic & equip list adequate BOPEs, do they meet regulation BOPE press rahng appropriate; test to "~ o~ Choke manifold complies w/APl RP-53 (May 84) Work wdl occur without operation shutdown Is presence of'H~S gas probable .......... __ _~ .,= WELl NAME .,~~ ~--Jf'..,/-.~'..2.(~ PROGRAM: exp ~ dev~redrll [] serv [] wellbore segl l ann disposal para r_eq X G E O[._O~G~Y GEOL AREA N N N N N N N N N N N N Y N C~,N ~N Perrl.t can be issued w/o hydrogen sulhde measures Data presented on potential 0verpressure zones Seismic analys~s of shallow gas zones Seabed condition survey (if off-shore) Contact name/phon,e.for weekly progress reports [exploratory on.~y] w~ii] proper cementing records, this plan (A) will contain waste in a suitable receiwng zone, (~ N (t~) will not contaminate fleshwater, o~ cause (hdhng waste ~ N to surface, (C) wdl not impair mechanical mtegnty of the well used for disposal, i~) N ([)) will not damage producing formahon or impmr recovery from a "~ N pool, and (E) will not c~rcumvent 20 AAC 25 252 or 20 AAC 25 412 ~ N ENGINEERING' UIC/Annular coMMISSION UNII'# /./_Z/~'~. ........ ON/OF F SHORE _.._C)_,~ Cornmentsllnstructions M Ihr, ldP~l ir ~ C,,, Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding informatiOn, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Thu Jun 17 14:23:17 1999 Reel Header Service name ............. LISTPE Date ..................... 99/06/17 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Tape Header Service name ............. LISTPE Date ..................... 99/06/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT, TARN POOL ~WD/M~D LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MWD RUN 2 AK-MM- 90068 G. GRIFFIN D. BURLEY RECEIVED JUN R 9 3999 Al~a ~ & Gas C, ons. C, om~n 2N-320 501032028700 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 17-JUN-99 MWD RUN 3 AK-MM- 90068 G. GRIFFIN D. BURLEY 3 09N 007 57 748 156.80 DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 156.80 120.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 108.0 9.875 7.625 3253.0 6.750 11061.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND NOT PRESENTED. 3. MWD RUNS 2 & 3 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND STABILIZED LITHO-DENSITY (SLD) . 4. GAMMA RAY DATA FROM 9430'MD, 4545'TVD TO 9500'MD, 4574'TVD) IS REAL TIME OWING TO DOWN-HOLE MEMORY LOSS. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E MAIL FROM D. SCHWARTZ OF ARCO ALASKA, INC. ON 5/20/99. MWD DATA IS PDC. 6. MWD RUNS 1-3 REPRESENT WELL 2N-320 WITH API~: 50-103-20287-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF ll061'MD, 5383'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. TNPS = COMPENSATED THERMAL NEUTRON POROSITY (SS MATRIX, FIXED HOLE SIZE). CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNTS. CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNTS. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR PHOTOELECTRIC ABSORPTION FACTOR (LOW COUNT BIN). PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.75" MUD WEIGHT: 9.1 TO 9.7 PPG MUD SALINITY: 450-650 PPM CHLORIDES FORMATION WATER SALINITY: 19149 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE START DEPTH NCNT 3263.0 FCNT 3263.0 NPHI 3263.0 PEF 3278.0 DRHO 3278.0 RHOB 3278.0 GR 3300.0 FET 3307.0 RPD 3307.0 RPM 3307.0 RPS 3307.0 RPX 3307.0 ROP 3353.5 $ BASELINE CURVE FOR SHIFTS: Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE $ REMARKS: STOP DEPTH 10969.5 10970.0 10970.0 10985.0 10985.0 10985.0 11007.0 11014.0 11014.0 11014.0 11014.0 11014.0 11061.0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 3265.0 6926.0 3 6927.0 11061.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type ..... ~ ............ 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 NPHI MWD P.U. 4 1 68 FCNT MWD CNTS 4 1 68 NCNTMWD CNTS 4 1 68 RHOB MWD G/CC 4 1 68 DRHO MWD G/CM 4 1 68 PEF MWD BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max DEPT 3263 11061 ROP 5.12 1763.69 GR 38.14 534 RPX 1.14 68.02 RPS 1.2 1095.92 RPM 1.19 71.4 RPD 1.26 61.3 FET 0.09 25.63 NPHI 12.86 56.97 FCNT 131.28 955.23 NCNT 14760.1 32130.9 RHOB 1.79 4.11 DP. HO -0.11 1.67 PEF 1.97 7.16 Mean Nsam 7162 15597 286.357 15416 123.691 15280 5.11104 15415 5.34039 15415 5.26968 15415 5.31974 15415 0.747099 15415 34.636 15415 275.139 15415 19979.9 15414 2.29053 15415 0.0189997 15415 2.66466 15415 First Reading 3263 3353.5 3300 3307 3307 3307 3307 3307 3263 3263 3263 3278 3278 3278 First Reading For Entire File .......... 3263 Last Reading For Entire File ........... 11061 Last Reading 11061 11061 11007 11014 11014 11014 11014 11014 10970 10970 10969.5 10985 10985 10985 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NCNT 3263 . 0 6835.0 FCNT 3263.0 6835.0 NPHI 3263.0 6835.0 PEF 3278.0 6850.5 DRHO 3278.0 6850.5 RHOB 3278.0 6850.5 GR 3300.0 6872.0 FET 3307.0 6879.0 RPD 3307 . 0 6879.0 RPM 3307.0 6879.0 RPS 3307.0 6879.0 RPX 3307.0 6879.0 ROP 3353 . 5 6927 . 0 $ LOG HEADER DATA DATE LOGGED: 05 - FEB - 99 SOFTWARE SURFACE SOFTWARE VERSION: INSITE 3.2. (UPGRADE 3) DOWNHOLE SOFTWARE VERSION: CIM 5.46, SP4 5.16, SLD 10.87 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 6926.0 TOP LOG INTERVAL (FT): 3265.0 BOTTOM LOG INTERVAL (FT): 6926.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 67.3 MAXIMUM ANGLE: 71.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 TOOL NUMBER Pll04GR4 Pll04GR4 CTN SLD $ COMP THERMAL NEUTRON STABILIZED LITHO DEN BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CA/fEAT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lIN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Pll04GR4 Pll04GR4 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD 2 FT/H 4 1 68 GR MWD 2 API 4 1 68 RPX MWD 2 OHMM 4 1 68 RPS MWD 2 OHMM 4 1 68 RPM MWD 2 OHMM 4 1 68 RPD MWD 2 OHMM 4 1 68 FET MWD 2 HOUR 4 1 68 NPHI MWD 2 P.U. 4 1 68 FCNT MWD 2 CNTS 4 1 68 NCNT MWD 2 CNTS 4 1 68 RHOB MWD 2 G/CC 4 1 68 6.750 6.8 LSND 9.40 46.0 9.0 500 5.6 3.200 1.858 4.200 3.600 .5 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 32.8 DRHO MWD 2 G/CC 4 1 68 PEF MWD 2 BARN 4 1 68 48 52 13 14 Name Min Max Mean DEPT 3263 ~ 6927 5095 ROP 5.12 1763.69 319.618 GR 38.14 175.88 112.828 RPX 2.48 44.52 4.67407 RPS 2.53 41.04 4.80032 RPM 2.09 71.4 4.80503 RPD 2.32 61.3 4.88143 FET 0.09 10.27 0.632977 NPHI 15.06 56.97 36.042 FCNT 131.28 793.67 249.058 NCNT 14760.1 31153.9 19260.8 RHOB 1.79 2.74 2.20557 DRHO -0.09 0.74 0.0134873 PEF 1.97 7.16 2.65367 Ns am 7329 7148 7145 7145 7145 7145 7145 7145 7145 7145 7145 7146 7146 7146 First Reading 3263 3353.5 3300 3307 3307 3307 3307 3307 3263 3263 3263 3278 3278 3278 Last Reading 6927 6927 6872 6879 6879 6879 6879 6879 6835 6835 6835 6850.5 6850.5 6850.5 First Reading For Entire File .......... 3263 Last Reading For Entire File ........... 6927 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH NCNT 6837.0 FCNT 6837.0 NPHI 6837.0 PEF 6851.0 DRHO 6851.0 RHOB 6851.0 GR 6872.5 FET 6879.5 RPD 6879.5 RPM 6879.5 RPS 6879.5 RPX 6879.5 ROP 6929.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 10.87 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10969.5 10970.0 10970.0 10985.0 10985.0 10985.0 11007.0 11014.0 11014.0 11014.0 11014.0 11014.0 11061.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE DGR EWR4 CTN SLD $ TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMP THERMAL NEUTRON STABILIZED LITHO DEN BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 08-FEB-99 INSITE 3.2.(UPGRADE 3) CIM 5.46,SP4 5.16,SLD MEMORY 11061.0 6927.0 11061.0 54.3 72.2 TOOL NUMBER Pll04GR4 Pll04GR4 Pll04GR4 Pll04GR4 6.750 6.8 LSND 9.60 43.0 9.0 450 5.6 4.100 1.820 5.400 4.600 44.5 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .5 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 3 FT/H 4 1 68 4 2 GR MWD 3 API 4 1 68 8 J 3 RPX MWD 3 OHMM 4 1 68 12 4 RPS MWD 3 OHMM 4 1 68 16 5 RPM MWD 3 OHMM 4 1 68 20 6 RPD MWD 3 OHMM 4 1 68 24 7 FET MWD 3 HOUR 4 1 68 28 8 NPHI MWD 3 P.U. 4 1 68 32 9 FCNT MWD 3 CNTS 4 1 68 36 10 NCNT MWD 3 CNTS 4 1 68 40 11 RHOB MWD 3 G/CC 4 1 68 44 12 DRHO MWD 3 G/CC 4 1 68 48 13 PEF MWD 3 BARN 4 1 68 52 14 First Name Min Max Mean Nsam Reading DEPT 6837 11061 8949 8449 6837 ROP 6.28 980.73 257.663 8265 6929 GR 61.01 534 133.233 8135 6872.5 RPX 1.14 68.02 5.48857 8270 6879.5 RPS 1.2 1095.92 5.80699 8270 6879.5 RPM 1.19 57.99 5.67112 8270 6879.5 RPD 1.26 51.86 5.69844 8270 6879.5 FET 0.12 25.63 0.845696 8270 6879.5 NPHI 12.86 54.41 33.4213 8267 6837 FCNT 152.76 955.23 297.678 8267 6837 NCNT 16179.7 32130.9 20601.3 8266 6837 RHOB 1.99 4.11 2.36395 8269 6851 DRHO -0.11 1.67 0.0237635 8269 6851 PEF 1.97 4.96 2.67416 8269 6851 Last Reading 11061 11061 11007 11014 11014 11014 11014 11014 10970 10970 10969.5 10985 10985 10985 First Reading For Entire File .......... 6837 Last Reading For Entire File ........... 11061 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/06/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/06/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 99/06/17 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File
