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184-104
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: Conductor ext. Development Exploratory 3. Address: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 7,145 feet feet true vertical 6,350 feet feet Effective Depth measured feet 6,483 & 6,656 feet true vertical feet 5,777 & 5,927 feet Perforation depth Measured depth 6,614'-6,800'feet True Vertical depth 5,891'-6,046'feet Tubing (size, grade, measured and true vertical depth)3.5" J-55 6,675' 5,944' Packers and SSSV (type, measured and true vertical depth)Packer CAMCO 6,483' 5,777' Packer BAKER 6,656' 5,927' SSSV SSSV 1,899' 1,893' 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: 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:Brennen Green/Roger Mouser Contact Email:N1927@conocophillips.com Authorized Title:WI Field Supervisor Contact Phone: 907-659-7506 324-676 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Gas-Mcf MD measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureWater-BblOil-Bbl 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 184-104 50-029-21138-00-00 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025655 KUPARUK RIVER/KUPARUK RIVER OIL ConocoPhillips Alaska P.O. Box 100360, Anchorage, AK 99510 KUPARUK RIV UNIT 2B-13 Plugs Junk measured N/A Length 74' 2,769' 110.8'Conductor Surface 16" 9 5/8" Size 110.8' 7"Production 7,077' Casing 6320'7,110' 2,804' measured TVD 2,738' Burst Collapse p k ft t Fra O s 184 6. A G L PG , t. Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E= n1927@conocophillips.com Reason: I am the author of this document Location: Date: 2025.08.12 13:12:59-08'00' Foxit PDF Editor Version: 13.1.6 Brennen Green By Grace Christianson at 1:23 pm, Aug 12, 2025 DSR-9/11/25JJL 9/5/25 RBDMS JSB 081425 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 12, 2025 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Please find the enclosed 10-404 from ConocoPhillips Alaska, Inc. for well KRU 2B-13 (PTD # 184-104) 10” Conductor extension. Please contact Brennen Green or Roger Mouser at 659-7506 if you have any questions. Sincerely, Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927@ conocophillips.com Reason: I am the author of this document Location: Date: 2025.08.12 13:12:24-08'00' Foxit PDF Editor Version: 13.1.6 Brennen Green Date Event Summary Executive Summary Welded Conductor Extension 12/17/24 Received AOGCC sundry # 324-676 for conductor extension 07/28/25 10" Tree Rise, Gas readings in the cellar and in the conductor: Normal 08/12/25 NES welders welded 16" x 10" x .500" conductor extension. 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6.API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A KUPARUK RIV UNIT 2B-13 Yes No 9. Property Designation (Lease Number):10. Field: KUPARUK RIVER 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 7,145 6,350 Casing Collapse Conductor Surface Production Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): CAMCO - 6,483'-5,777' BAKER FB1 PACKER SSSV - 1,899' - 1,893 BAKER - 6,656' -5,927' 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: 907-659-7506 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 6,614'-6,800' 7,077' 5,891'-6,046' Feburary 28,2025 3.5" 6,320'7" 16" 9 5/8" 74' 2,769' 7,110' Burst 6,675' MD 110' 2,738' 110' 2,804' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025655 184-104 P.O. Box 100360, Anchorage, AK 99510 50-029-21138-00-00 ConocoPhillips Alaska Proposed Pools: AOGCC USE ONLY Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): J-55 Perforation Depth MD (ft): Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY WI Field Supervisor KUPARUK RIVER OIL Other: Conductor Ext PACKER-CAMCO 'HRP-1-SP' PACKER SAFETY VALVE - OTIS FMX (locked out) Brennen Green/ Roger Mouser N1927@conocophillips.com Length Size TVD m n P 1 6 5 6 t t N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927 @conocophillips.com Reason: I am the author of this document Location: Date: 2024.11.29 16:05:24-09'00' Foxit PDF Editor Version: 13.0.0 Brennen Green 324-676 By Grace Christianson at 7:52 am, Dec 02, 2024 DSR-12/16/24JJL 12/03/24 10-404 *&:SFD 12/17/2024 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.12.17 09:09:19 -09'00'12/17/24 RBDMS JSB 121924 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 29,2024 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Please find the enclosed 10-403 application for Sundry Approval from ConocoPhillips Alaska, Inc. for well KRU 2B-13 (PTD 184-104) to extend the conductor. Summary: Conductor has subsided or well has grown ~11” or more. With AOGCC approval we would like to add conductor material to cover the production casing. Please contact Brennen Green or Roger Mouser at 659-7506 if you have any questions. Sincerely, Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. ConocoPhillips Alaska, Inc. Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927@ conocophillips.com Reason: I am the author of this document Location: Date: 2024.11.29 16:03:57-09'00' Foxit PDF Editor Version: 13.0.0 Brennen Green P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Kuparuk Well 2B-13 (PTD 184-104) SUNDRY NOTICE 10-403 APPROVAL REQUEST November 29, 2024 This application for Sundry approval for Kuparuk Well 2B-13 is to extend the conductor to original height to stabilize tree and prevent corrosion to the surface casing. At some point during normal operations the conductor subsided or the well has grown ~11”. With approval, the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Extend the conductor to starter head. 3. File 10-404 with the AOGCC post repair. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 6,771.0 2B-13 7/12/2022 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Tag 2B-13 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: NOTE: Surf CSG patch BTM of starter head to top of 1st SC collar (OAL=47") 10", .500 X65 pipe 6/22/2010 lmosbor NOTE: View Schematic w/ Alaska Schematic9.0 2/27/2010 ninam Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 36.0 110.0 110.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 35.2 2,804.4 2,738.1 36.00 J-55 BTC PRODUCTION 7 6.28 32.7 7,109.7 6,320.2 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 30.4 Set Depth (ftK 6,674.6 Set Depth (TV 5,944.0 String Max Nomin 31/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection IPC8rd ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB)Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 30.4 30.4 0.04 HANGER 8.500 GREY TUBING HANGER 3.500 1,899.3 1,898.3 8.43 SAFETY VLV 5.937 OTIS 'FMX' (LOCKED OUT 2/5/2004) 2.813 1,939.0 1,937.5 9.58 GAS LIFT 5.390 Camco KBUG 2.920 3,677.3 3,455.7 35.28 GAS LIFT 5.390 Camco KBUG 2.875 5,069.5 4,589.1 34.49 GAS LIFT 5.390 Camco KBUG 2.920 5,975.9 5,345.8 32.81 GAS LIFT 5.390 Camco KBUG 2.920 6,422.9 5,725.7 30.46 GAS LIFT 5.390 Camco KBUG 2.920 6,464.9 5,761.9 30.25 PBR 3.750 'OEJ' PBR Camco 2.950 6,482.7 5,777.3 30.16 PACKER 7.000 'HRP-1-SP' PACKER Camco 2.875 6,522.8 5,812.0 29.94 PRODUCTION 5.390 Camco KBUG 2.920 6,592.9 5,872.9 29.54 PRODUCTION 5.390 Camco KBUG 2.920 6,599.4 5,878.5 29.50 BLAST JT 4.500 BLAST JOINT (1) 2.867 6,644.1 5,917.5 29.60 PRODUCTION 5.390 Camco KBUG 2.920 6,654.6 5,926.6 29.63 LOCATOR 4.000 LOCATOR w/ PACKER Seal Assy Baker 3.000 6,655.5 5,927.3 29.63 PACKER 5.500 FB1 PACKER Baker 4.000 6,658.0 5,929.5 29.63 SBE 5.500 SEAL BORE EXTENSION Baker 4.000 6,668.3 5,938.5 29.66 NIPPLE 4.500 NO GO 'D' NIPPLE Camco 2.750 6,673.8 5,943.3 29.67 SOS 3.500 DE 500 PUMP OUT PLUG / ELMD TTL @ 6668' PER OTIS FLUID LOG 2/8/1985 Camco 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°) Des Com Make Model SN Run Date ID (in) 6,578.0 5,860.0 29.63 PATCH 21.5' Merla Tbg Patch, Set across GLM #7 set 9/16/1990 9/16/1990 2.375 6,613.0 5,890.4 29.53 PATCH 22' Merla Tbg Patch w/ XN Nipple Profile, set across hole in Blast Joints, DO NOT EXCEED 1000 PSI when PT agaist this profile 9/13/1990 2.250 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No Serv Valve Type Latch Type OD (in) TRO Run (psi)Run Date Com Make Model Port Size (in) 1,939.0 1,937.5 9.58 1 GAS LIFT GLV BK 1 1,254.0 9/20/2021 0.188 3,677.3 3,455.7 35.28 2 GAS LIFT GLV BK 1 1,258.0 9/20/2021 0.188 5,069.5 4,589.1 34.49 3 GAS LIFT OV BK 1 0.0 9/19/2021 0.188 5,975.9 5,345.8 32.81 4 GAS LIFT DMY BK 1 0.0 9/19/2021 0.000 6,422.9 5,725.7 30.46 5 GAS LIFT DMY BK 1 0.0 6/24/2010 0.000 6,522.8 5,812.0 29.94 6 PROD DMY BEK 1 0.0 9/5/2015 EXT PKG 0.000 6,592.9 5,872.9 29.54 7 PROD Patch BK 1 0.0 9/16/1990 0.000 6,644.1 5,917.5 29.60 8 PROD DMY BK 1 0.0 9/16/1990 Clsd 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 6,614.0 6,630.0 5,891.3 5,905.2 C-4, 2B-13 10/20/1984 12.0 IPERF BLOCKED BY PATCH set 9/13/1990 6,713.0 6,720.0 5,977.3 5,983.4 A-5, 2B-13 12/19/2018 6.0 APERF 2" PJ, 6-SPF, 60° phasing 6,730.0 6,744.0 5,992.1 6,004.2 A-4, 2B-13 10/20/1984 4.0 IPERF 4" HJ II; 90 deg. phase 6,730.0 6,744.0 5,992.1 6,004.2 A-4, 2B-13 12/19/2018 6.0 RPERF 2" PJ, 6-SPF, 60° phasing 6,764.0 6,792.0 6,021.5 6,045.7 A-3, 2B-13 10/20/1984 4.0 IPERF 4" HJ II; 90 deg. phase 6,764.0 6,780.0 6,021.5 6,035.3 A-3, 2B-13 1/11/2019 6.0 RPERF 2" PJ, 6-SPF, 60° phasing 6,780.0 6,792.0 6,035.3 6,045.7 A-3, 2B-13 1/11/2019 6.0 RPERF 2" PJ, 6-SPF, 60° phasing 6,792.0 6,800.0 6,045.7 6,052.6 A-3, 2B-13 1/11/2019 6.0 APERF 2" PJ, 6-SPF, 60° phasing 2B-13, 11/29/2024 3:57:25 PM Vertical schematic (actual) PRODUCTION; 32.7-7,109.7 FLOAT SHOE; 7,108.3-7,109.7 FLOAT COLLAR; 7,027.8-7,029.3 APERF; 6,792.0-6,800.0 RPERF; 6,780.0-6,792.0 IPERF; 6,764.0-6,792.0 RPERF; 6,764.0-6,780.0 RPERF; 6,730.0-6,744.0 IPERF; 6,730.0-6,744.0 APERF; 6,713.0-6,720.0 SOS; 6,673.8 NIPPLE; 6,668.3 SBE; 6,658.0 PACKER; 6,655.5 LOCATOR; 6,654.6 PRODUCTION; 6,644.1 PATCH; 6,613.0 IPERF; 6,614.0-6,630.0 PRODUCTION; 6,592.9 PATCH; 6,578.0 PRODUCTION; 6,522.8 PACKER; 6,482.7 PBR; 6,464.9 GAS LIFT; 6,422.9 GAS LIFT; 5,975.9 GAS LIFT; 5,069.5 GAS LIFT; 3,677.3 SURFACE; 35.2-2,804.4 FLOAT SHOE; 2,802.6-2,804.4 FLOAT COLLAR; 2,722.0-2,723.6 GAS LIFT; 1,939.0 SAFETY VLV; 1,899.3 CONDUCTOR; 36.0-110.0 CSG HANGER; 35.2-39.4 HANGER; 30.4 KUP PROD KB-Grd (ft) 41.60 RR Date 10/20/198 Other Elevatio 2B-13 ... TD Act Btm (ftKB) 7,145.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292113800 Wellbore Status PROD Max Angle & MD Incl (°) 35.83 MD (ftKB) 4,400.00 WELLNAME WELLBORE2B-13 Annotation Last WO: End DateH2S (ppm) 38 Date 7/5/2023 Comment SSSV: LOCKED OUT TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop 2AͲ25 50Ͳ103Ͳ20239Ͳ00 196062_2AͲ25_LDL_15Jul2022 196062_2AͲ25_Patch_12Jun2022 2BͲ01 50Ͳ029Ͳ21147Ͳ00 184115_2BͲ01_PPROF_18Feb2023 2BͲ02A 50Ͳ029Ͳ21154Ͳ00 184122_2BͲ02A_LDL_26Jul2023 2BͲ13 50Ͳ029Ͳ21138Ͳ00 184104_2BͲ13_PPROF_02Jun2023 2DͲ07 50Ͳ029Ͳ21169Ͳ00 184143_2DͲ07_IPROF_10Jun2023 2DͲ08 50Ͳ029Ͳ21158Ͳ00 184127_2DͲ08_PPROF_28May2023 2DͲ13 50Ͳ029Ͳ21070Ͳ00 184012_2DͲ13_PPROF_03Jun2023 2DͲ15 50Ͳ029Ͳ21184Ͳ00 184160_2DͲ15_PPROF_04Jun2023 _2EͲ10 50Ͳ029Ͳ21246Ͳ00 184230_2EͲ10_CBL PostͲBiSN_21Aug2023 184230_2EͲ10_CBL PreͲBiSN_28Jul2023 2FͲ13 50Ͳ029Ͳ21032Ͳ00 183156_2FͲ13_WFL_29Jun2023 2HͲ02 50Ͳ103Ͳ20032Ͳ00 184073_2HͲ02_IPROFͲWFL_13Jun2023 6 of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38362 T38363 T38364 T38365 T38366 T38367 T38368 T38369 T38370 T38371 T38733 216-087 2BͲ13 50Ͳ029Ͳ21138Ͳ00 184104_2BͲ13_PPROF_02Jun2023 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.23 11:48:05 -08'00' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS I4'�97r.'. FEB 0 6 20 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑Q Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑erforale New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Development + ❑ Exploratory p [-]184-104 Stratigraphic❑ Service ❑ 3. Address: P. O. Box 100360, Anchorage, Alaska 6. API Number: 99510 50-029-21138-00 7. Property Designation (Lease Number):8. Well Name and Number: ADL 25655, ALK 2581 KRU 28-13 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 7,145 feet Plugs measured None feet true vertical 6,351 feet Junk measured None feet Effective Depth measured 7,145 feet Packer measured 6483, 6656 feet true vertical 6,351 feet we vertical 5777, 5927 feet Casing Length size MD TVD Burst Collapse CONDUCTOR 74 feet 16 110' MD 110' TVD SURFACE 2,769 feet 9 5/8 " 2,804' MD 2738' TVD PRODUCTION 7,077 feet 7 7,110' MD 6320' TVD Perforation depth: Measured depth: 6713-6720. 6764.6792, 6764-6780 6780-6792, 6792-6800 feet True Vertical depth: 6021-6035, 5977-5983, 6021-6035 6035.6046 6046-6063 feet Tubing (size, grade, measured and true vertical depth) 3.5 " J-55 6,675' MD 5,944' TVD Packers and SSSV (type, measured and true vertical depth) PACKER - CAMCO'HRP-I-SP' PACKER 6,483' MD 5,777' TVD PACKER - BAKER FB1 PACKER 6,656' MD 5,927' TVD SAFETY VLV- OTIS'FMX'(LOCKED OUT 21512004) 1,899- MID 1,893'TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): NIA 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: 86 190 618 1067 155 Subsequent to operation: 105 245 758 1092 152 14. Attachments (required per 20 AAC 25.070, 25.071, s 25.z83) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development El Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Q Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NIA Contact Name: Steve Drake Authorized Name: Steve Drake Contact Email: Steve.G.Drake@cop.com Authorized Title: Sr. Wells Engineer Contact Phone: (907) 263-4062 Authorized Signature: 15-111 Date: Form 10-404 Revised 4/2017 V7—t- ?147-11% _ RBDMSSY_-FSR 1 12019 Submit Original Only 2B-13 PERFORATE DTTMSTPJOBTYP SUMMARYOPS 12/19/18 PUMPING FREEZE PROTECT TRACKING PUMPED 20 BBLS DSL DOWN TBG 12/19/18 ANNCOMM RIH W/2" GUNS. TAGGED @6772'. GUN 1: PERFORATED INTERVAL 6730'- 6744', CCL TO TOP SHOT = 5.25', CCL STOP DEPTH = 6724.75' LOG CORRELATED TO SLB CBL DATED 10/7/1984. GUN 2: PERFORATED INTERVAL: 6713'- 6720', CCL TO TOP SHOT = 6.25', CCL STOP DEPTH = 6706.75'. LOG CORRELATED TO SLB CBL DATED 10/7/1984. 1/1/19 ANNCOMM RIH TO PERFORM NITROFIED FCO, N2 CREW DELAYED DUE TO RIG MOVE, SLB INJECTOR BEGINS RUNNING BADLY CAUSING THE MAST OF THE COIL UNIT TO SWAY BACK AND FORTH, RELEASE HES N2 CREW AND HAVE SLB MECHANIC COME OUT TO TROUBLESHOOT THE ISSUE. JOB IN PROGRESS. 1/2/19 ANNCOMM PERFORMED NITRIFIED FILL CLEANOUT FROM 6822' CTMD TO HARD TAG AT 7010' CTMD PUMPING SLICK DIESEL AND DIESEL GEL SWEEPS AT 1 BPM, N2 AT 750 SCFM (EST. 210' OF RATHOLE BELOW LOWEST E -LINE PERF DEPTH) MAINTAINED 1:1 RETURNS THROUGHOUT CLEANOUT, LIGHT SAND CONCENTRATIONS OBSERVED, EST TOTAL SOLIDS VOLUME AT 7 BBLS, COMPLETED WEEKLY BOP TEST, READY FOR SLICKLINE 1/3/19 ANNCOMM TAG @ 6927' RKB (EST. 135RAT HOLE); DRIFT W/ 20'x 2.16" DMY PERF GUNS TO TAG @ 6927' RKB. READY FOR E -LINE. 1/10/19 ANNCOMM PLANNED TO PERFORATE TODAY BUT WAS SHUT DOWN DUE TO ISSUES WITH THE CRANE. 1/11/19 ANNCOMM RIH W/ 2" GUNS. GUN 1: PERFORATED INTERVAL: 6780'- 6800'. GUN FIRED WITH GOOD INDICATION. GUN 2: PERFORATED INTERVAL: 6764'- 6780'. GUN FIRED WITH GOOD INDICATION. KUP PROD WELLNAME 2B-13 WELLBORE 2B-13 ,�� ' fr..' ' Well Attrihutes Max Angle & MD TD CO(1000PF1U�ip5 tlN I OD 91ap8001 W.Femeadmus R,-, . anvil) act.,.Inam Alefikfl,InC. (KUPARUK RIVER UNIT (PROD SA3 440000 71450 OCKED OUT est WO: 28-pl a ads l l:too. AM Last Tag vareu rclrnaEc (vben annotation Depth QMB) 1 End Data wellWre LaM MOB er Last Tag: RED ON".0 I1/3/2019 28-13 1 (ergosp HANGER; 30.4 Last Rev Reason Annotation End DR. WenMre feel MpC 9v Rev Reason Perforate A -Sand 111112019 26-13 lb.0h, Casing Strings Casing Descrimon oDQn lo(nf Top(X6ef sif a lnHef set seem rvD,_. wulen p... crbe Top rn2eJ CONDUCTOR 16 15.06 36.0 110.0 110.0 62.50 H-00 WELDED Casing Oescriane. OD lint Had TaP Met SN Dapm Mel BM Dpath IND)... NWLen II_. Grade Top Theme 11. SURFACE 9518 8,92 35.2 2,804.4 1)38.1 36.00 J-55 BTC Casing Description (in) tin) Tap IM(e) SN-IM(Bf eN Damm ITVD)... WSLen 9... GladO Top TMu! CONDUCTOR: W DUOO IOD 1w PRODUCTION 7 628 32.7 ),109.] 6,3202 28.00 J-55 BTC Tubing Strings S4FETYVLV, t,ms.3 Tuning DescripM1an amng Ma... IDilnf TOp IXHBf set Depth l4.. 5el Depin l Df I...NFLIM G,ada TopcannMion TUBING 3112 2.99 304 66)4.6 5944.0 9.30 J-55 IPCBrb DAs UFT; 1.s3po Completion Details pm ENO) Tap mc+ Human Tnpehal (nn.) 19 nem Des Cam mpnl 304 304 004 HANGER GREY TUBING HANGER 3.500 1,899.3 1,8983 843 SAFETY VLV OTIS'Fell (LOCKED OUT 2151 2.813 SURFACE: 35.?IW4A� 6,464.9 5,761.9 3025 HEIR CANDO'DES PBR 29M 6,4827 5,7773 30.16 PACKER CAMCO 'HRP-I-SP'PACKER 2875 GAs uFr: aen.3 6.5994 5,878.5 29.50 BIA TJT BLAST JOINT (1) 2,867 6,654LOBA .6 5,926.6 29.63 CATOR KERLOCATOR w/A KERSEAL ASSEMBLY 3.000 GAB UPT; s,O®s 6,655.5 5,927.3 PACKER BAKER FBI PACKER 4.000 --21 aspi 1,,.. 6658.0 5929.5 SBE BAKER SEAL BORE EXTENSION 4.0 5.6683 1 5,938.5 2.6 NIPPLE CAMCO NO GO D'NIPPLE 2.750 GAs uFr:4rz2.e 6,6)3.8 1 5,943.3 1 29.6] SOS M DE 500 PUMP OUT ILL5717eal I I L ou empH'PER 299 OTIS FLUID LOG 21811985 PBR;846s.8 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etoJ ToEhil TOpIrvD) I4Ke+ hm(lIml (I Des Co. Run Date 10 (in) PPCNER; B,aB2] 6,578.0 5, 0.0 2963 PATCH 21.5' Merle Tag Patch, get across GEM N) set 911611990 2.375 PRog1CTICN; B,SY1b 9161990 6,613.0 5,6904 2953 PATCH ZY Meda Tbg Patch w N Nipple r0 le, sal across 911311990 2 250 hole in Blast Joints, DO NOT EXCEED 1000 PBI veden PATCH; 4s]8.o PT agaist Nis profile PRODUCTK3N:6.52.e Perforations & Slots Shat Dans Tap(ND) ..(No) (Sha Top Iws) St.me) IHHe1 (heB) 1.nmd Z0m Dale ) Type Cam 6.614B ,63 0 5891.3 5,905.2 Cd, 20-13 102011984 12.0 (PERF B A H set 9/1311990 IPERF;8.81008.630.0 PATCK4filao 6] ) 0 5,9]].3 5,983.4 A -52B-13 17192018 60 APE F deg phasing 8,7 0. ,744 0 5,992.1 6,0042 Ad, 28-13 102N1984 4.0 IPERF 4" HJ If; 90 tleg. ph se 6,]30. ,744.0 5992.1 60042 A4,28-1 12/192018 60 RPERF =lRi phasing 6,]84. )92.0 6,0215 8,045.] A-3, 28-13 1W2011984 4.0 IPERF 4" HJ II; 90 tleg. phase 8,7 6 780 0 6,021.5 6,035.3 A3, 2B-13 1111/1 SO RPERF 2 Pj. 6 -SPF -tleg phasing 1 PRODUCTION;flasta 6,781 6,7920 6,035.3 6,0453 A-3, 2B-13 11112019 6.0 RPERF phasing SPF, deg phasing 1 LOCAioN;4ea3.9 6792.0 6.8000 6,0457 6052.8 A3, 2B-13 1/1WON 80 APERFeg al PACKER.4e5S5 phasing BBE; 4654.0 Mandmi Inserts SI atl INPFLE:4fiM.3 N TOpIND) Valve Wch PaNStee TRO Run TO, pi Meke Fill OD On, eery type Type (In) (psi) Run Date Cam 1 1, 90 1,93]5 CAMCO KBU 1 GAS LIFT GLV BK 0.125 1,213.0 6272010 508. e.eyae 77.3 3.4557 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,255.0 6/27/2010 3 5, 5 4,5891 CANDO KBUG 1 GAS LIFT GLV BK 0.1 1,298.0 62)12010 4 5, 75. 5.345.8 CAMCO KBUG 1 GAB LIFT OV BK 0.188 0.0 WlIM12 5 8,4 5.)25.] CAMCO KBU 1 GAB LIFT DMY BK 0.000 0.0 62412010 6 6, 5,8120 CAMCO KBUG 1 PROD DMY BEK 0.000 0.0 8/52015 % APERF;4naoa,Trv.O- PKG ] 6,5929 5,872.9 CAMCO KBUG 1 PROD Patch BK 0.000 0.0 911611990 8 6,644.1 5,917.5 CAMCO KBUG 1 PROD DMY BK 0.000 0.0 911611990 RPERF:67f0"7M.0 IPERF; e,]y1.047M.0� (.`I03a0 Notes: General S, Safety EM Data Annaf . 2127/2010 NOTE:VIaw Schematic w/ Alaska SCh ... aC9.0 N22IX to j.l NOTE: SUIT CSG patch BTM 01 staler head to top 0f 1st SC Cellar (OAL=47')10", .500 X65 pipe Hpsp. 4]84D4701 I"HIP .7.F 8,]n20 PPERF:4TM.O4R20� PFERF: fi.ig2.O6.Mg0� PRODDCTION, so 7 T.IW1 General Well Work Request Form Well: 20-13 Date of Request: 12/7/2018 Request SPOC: CPF2 PE David/Stephanie x7519, pgr 252 Well Type: Producer Req. Written by: Steve Drake, 263-4062 Job Scope: Pert -E -Line Shut -In Reason Code: 260 Perforate / Pert Support Well Shut in Date (if SI): Prioritization Category: Opportunity/Rate Adding Budget Category: Kuparuk Base Expense Network: 10412729 Job I SAP Comment: ❑Well Work is not justified via increased production ❑Preventive Maintenance Program Request Current Well Data After Well Work Data Current Oil Rate (BOPD) 89 Post -Job Oil Rate (BOPD) 10 Risked NOB (BOPD) -75 Last SBHP 2500 psi Last Tag 7,021'md H28 (PPM): 75'ppm SBHP Date 9/2812014 Tag Date 1115/2018 Any Fluid Restriction on Well? SBHP Datum (TVD/SS?) 6200 SS Max Inclin. 36' Max Dogleg 4° / 100' and Min. LD (at/above work) 2.25" Max Incl. Depth 4,400'md Max Dogleg Depth 1,800'md Well Work Justification & Objectives: 28-13 is an A/C sand producer. This procedure will outline the steps to reperforate the existing A sand perforations (and add some perfs) in an effort to increase production. Rev1 12/29/18 SRP: On 12/19, a -line tagged at 6772' ELMD so were unable to perforate the lower two intervals requested. The well needs an FCO followed by a slickline drift before a -line perfs. Risk/Job Concerns: 2.25" ID Patch @ 6,613' RKB (22' OAL) 2.375" ID Patch @ 6,578' RKB (21.5' OAL) Well was drifted on 11/8/18 with 20' of 2.135" dummy drift. Stall/stop @ 6777' RKB. Fill was tagged with a 1.875" sample bailer at 6918' RKB. Dummy drift run was only drifted to 6777' RKB. May need to work through 6775- 6777' area to perforate on first run. See LOG tab in this Excel Workbook for Gamma reference to tie in. Steps: Coiled Tubing: Based on last SBHP (9/28/14) reservoir pressure mud weight equivalent is 7.75 ppg but during FCO on 1/15/18, needed nitrified diesel to get returns. Minimum ID = 2.25"patch at 6613' RKB. 1. MIRU. PJSM. 2. RIH with 15N to dry tag. E -line tagged at 6772' ELMD 12/19 and well has been online since. 3. Clean out at least 6850' RKB (50' of rat hole below bottom desired perf depth) or as deep as possible if job is going well (coil wells supervisor's discretion). 4. POOH. RDMO. Turn well over to DSO to bring back online. Slickllne: 1. MIRU. PJSM. 2. Drift for 20' perf gun run specified below and tag TD. 3. RDMO. Turn well over to D50 to bring back online. Eline: 1. MIRU EL and associated support equipment. 2. MU and RIH with 20' of 2" PJ perf gun (max swell = 2.16"). 3. Perforate zones from 6780-6800' RKB. POOH. 4. MU and RIH with 16' of 2" PJ perf gun and perforate from 6764-6780' RKB. POOH. 9. N411 and RIM with 14'ef 2" Pi peFf guA and PBFfOFate fFem 6730 674 4' RKS. . Done 12/19. and Rill ith -r _r 2" PJ ..,..t ......,n peFl..-_«., si em 6713 6720 RKS onnu Done 12/19. 7. RDMO. Turn well over to operations to be BOL. 28-13 Perforate 12072018 531)_rev112-29.xlsm Printed 1/24/2019 2.55/ 2 WELL LOG TRANSMITTAL DATA LOGGED f2y2O15 M.K.BENDER To: Alaska Oil and Gas Conservation Comm. March 5, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 'RECEIVED MAR 242015 RE: Production Profile: 2B-13 C Run Date: 2/18/2015 �� The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2B-13 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-21138-00 Production Profile Log 1 Color Log 50-029-21138-00 SCARE) . 4 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com 121Ia,12.a tz k- Date: Signed: 6-€4f-eat i ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 1, 2010 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 \~~ ~~ ~~~ \~ ,'~~ ,~.~, ~~j, lil~il'i ~;., Commissioner Dan Seamount: • ~ ~ ~- Sg~oa ~G Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped July 21St. The corrosion inhibitor/sealant was pumped July 30th, 31St 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off ~ I Report of Sundry Operations (10-404) Kuparuk Field Date 8/01/10 ~n ~u 7T DA1'1 ell Name PI # TD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date ~,~ .,~ Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2B-13 50029211380000 1841040 64" 0.4 11" 7/21/2010 1.7 7/31/2010 2K-16 50103201150000 1890940 SF n/a 19" n/a 2.8 7/31/2010 2K-20 50103201200000 1891180 10" n/a 10" n/a 2 7/31/2010 2K-23 50103201250000 1900140 SF n/a 18" n/a 2.6 7/31/2010 2K-24 50103201220000 1891300 SF n/a 18" n/a 2,6 7/31/2010 2T-07 50103200690000 1861080 17" n/a 17" n/a 5.1 7/30/2010 2T-19 50103202140000 1950260 18" n/a 8" n/a 2 7/30/2010 2T-20 50103202150000 1950290 SF n/a 23" n/a 2.6 7/30/2010 2T-21 50103202120000 1950130 SF n/a 21" n/a 3.4 7/30/2010 2T-26 50103202230000 1950820 SF n/a 27" n/a 4.3 7/30/2010 2T-29A 50103202220100 2091360 SF n/a 29" n/a 7.7 7!30/2010 2T-30 50103202190000 1950570 SF n!a 30" n/a 6 7/30/2010 2T-31 50103202260000 1950990 30" n/a 30" n/a 6 7/30/2010 2T-36 50103202280000 1951020 SF 0.40 12" 7/21/2010 2.6 7/30/2010 2T-39 50103203920000 2011830 30" 0.54 14" 7/21/2010 4.3 7/30/2010 2T-201 50103202300000 1951220 60" 1.57 32" 7/21!2010 7.7 7/30/2010 2T-204 50103203270000 2000160 SF n/a 24" n/a 5.1 7/31/2010 2T-209 50103202810000 1982430 40" 1.20 19" 7/21/2010 4.8 7/31/2010 2T-218 50103204490000 2030170 31" 0.73 9" 7/21/2010 2.6 7/31/2010 2T-220 50103202830000 1982530 38" 0.49 19" 7/21/2010 5.1 7/31/2010 • • Conoco~Phll~ps ~~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 25, 2010 ~.. .: . ,. Mr. Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Seamount: Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc., we112B-13, PTD 184-104, Sundry 310-162, gas lift producer surface casing repair. Please call MJ Loveland or Perry Klein at 659-7043 if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon [ Repair w ell ^ Plug Perforations Q Stirrxilate Q Other 0 SC Welded patch ARer Casing (~ Pull Tubing Q Perforate New Pool [ Waiver ® Time Extension Change Approved Program ~"j Operat. Shutdow n Q Perforate Qj Re-enter Suspended Well [~ 2.Operator Name: 4. Current Well Status: `°~. S. Permit to Drill Number: ConocoPhillips Alaska Inc. Development ~; Exploratory ^ 184-104 , 3. Address: Stratigraphic ^ Service ^ `~.6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21138-00 7. Property DesigCation: 8. Well Name and Number: ~ ADL 0025655 ALK 2581 26-13 9. Field/Pool(s): K paruk Oil Pool Kuparuk River Field / 10. Present Well Condition Summary: Total Depth measured 7145 feet Plugs (measured) None true vertical 6351 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 6483, 6578, 6613, 6655 true vertical 0 feet (true vertucal) 5777, 5860, 5890, 5927 Casing Length Size MD TVD Burst Collapse CONDUCTOR 74 16 110 110 na na SURFACE 2769 9.625 2804 2738 3520 2020 PRODUCTION 7077 7 7110 6320 4980 4320 Sleeve 47" 10" 47" 0 0 0 0 0 0 0 0 0 p C~~~~,D ' , ~ 1~: Perforation depth: Measured depth: 6614-6630, 6730-6744, 6764-6792 1 ~ 2010 True Vertical Depth: 5891-5905, 5992-6004, 6021-6045 ~ nIUN r Cis. Commission ska Ot•1 ~ ~~ MD and TVD) 3 i e rade T bi 6674 MD 55 5943 TVD Al 5 J , z , g , u ng (s , , . , - a =~nolter~ge Packers & SSSV (type, MD, and TVD) PACKER - CAMCO'HRP-1-SP' PACKER @ 6483 MD and 5777 TVD PATCH - 21.5' MERLA TBG PATCH, SET ACROSS GLM #7 SET 9/16/1990 @ 6578 MD and 5860 TVD PATCH - 22' MERLA TBG PATCH; SET ACROSS HOLE IN BLAST JOINTS 9/13/1990 @ 6613 MD and 5 PACKER -BAKER F61 PACKER @ 6655 MD and 5927 TVD SAFETY VLV - OTIS'FMX' (LOCKED OUT 2/5/2004) @ 1899 MD and 1898 TVD 11. Stimulation or cement squeeze summary: NA Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12, 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 13. Attachments 4. Well Class after proposed work: Copies of Logs and Surveys run Exploratory Qj Development [~„( Service . Well Status after work: Oil ~ Gas ^ WDSPL Q Daily Report of Well Operations _X GSTOR Q WAG ^ GASINJ Q WINJ Q SPLUG [{ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. sundry Number or NiA if c.o. Exempt 310-162 contact Perry Klein / MJ Loveland Printed Name MJ Loveland itle Well Integrity Projects Phone: 659-7043 Date 6/25/10 Signature @_ - / ~w Form 10-40~Revised 7!2009 R6DMS lUN ~~ J ~!''~~r Submit Original Only • • 26-13 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 06/11/10 Remove 57" of conductor and confirm leak 18" below starter head flutes. 06/12/10 i Meet with Kakivik for UT inspection on SC for sleeve installation. Base metal on SC above collar is .343" thick, base metal on SC below flutes is .338" thick. From the bottom of the starter head to the top of the collar is 48". 06112!10 Notified stateman (John Crisp of opportuni to witness exposed SC to be re aired. 06/20/10 06121/10 Started hot work and confined space permits. Held PJSM on location. Cooper heat pre heated starter head. Welders welded a 47" patch fabbed from 10" .500 wall X65 pipe per M.E. specs. Allow welds to cool over night for Kakivik to inspect welds. Kakivik UT/MT inspection and Insulators Denso Wrap on SC. Preformed MITOA (PASSED). Initial T/I/O = 0(si)/25/0. Pressure up with .5 barrels of diesel. Start T/I/O = 0/25/1800. 15 min. T/I/O = 0/25/1700. 30 min. T/I/O = 0/25/1675.45 min. T/I/O = 0/25/1675. 60 min T/I/0= 0/25/1675. Bleed IA and OA down to zero. Final T/I/O = 0(si)/0/0. 06/25/10 Install 64" of 16" .375 wall conductor. I ~tv~ i,sr[ '~ ~, E t. .. :, .. ~ q ~ k .,, ., -~ .~ . ~" ~- _ a a *~ ,.z ,. - * , < ~~_ .~. 4 „ r' .w w ,a 1 ¢: ~, ~ } iC P ,~ ~.. 41 ,~ i '4. ~,~ 1 ,. ~'. ' .ff,1 ~111kkkk • ,. T, ~X `~ N~ ~", ~ ~ ., -- ~'' ~q ,n k may, , +~,; « ~.w~ ~ f r W - . r. ~. ~ ~ - t ~ " r+t s ~~ x 9t ' ,~ - .~ C ~: ~ r ~* ~_. o- yr .{ ~~ ~~ w { • ~ ~ d x m+ ,... ~ ~ ~ ~ ~ , ,. ~` ~.!~ ~ x~ ,. ~~ - ~.TE~ ~ ,....K ~~ k j~ y. - ~ .: ~ . ,' P ^> . , .~ . . ,~ I k :. ~ _~ K .~ ~ ta~ o n~o h i I . as a :.,, P ~. - i ps :A ~~ ~ ~ t = ~ „~ `~ ~ . ~ , ..~~ it ti 4m ~A ~ ~ ~~~~ ~~s ~~~ .~'i This phi-this oopyright b~ s ~~ ~ ~ ~ ~~: Cony= oPhilli s Alaska I ~~ ~='~ ~. ~; ~` ~~ ~ and ~nnot be re~eased~ ~ y$ ,,~. -~ ~ published~ithout express :~ ~ _ ~~ -~ ~. . ~ ~ . ~..,,: v~ritten consent of A 'a i n . ~ ~r 4 ~- r a.. ~ ~ ' ~ono~oPhillips Alask ~ .r _ ~, ~;: ~ ~1± ,~ k ~ i .~ ._._ x - "s r . ., ~ 'ti¢ ~ ~ YyAs ,' ~ ~ il~ ~ h t ~Pri `x" ,~ ,,d~u -T. . e'er ` . .. ~ .- .. k! ~. r. r~ ~ yy: a ~ #: ~:' ~ v F= x.~.r Ys Y t p `~~ re `; ~ P ~ ,~r3 f ,e~s ~ ~ .. 1 ~ ~ ,P'y ~~ Y °~i~~-~~ ~/'\J ~s ~ r~ to ~ ' g~~~~y ~_:' _ ~ ~ ~ _ ~ p V ' ~Ph ~~ ~ ~~~~ J ~~ ~a ~ a 5 ~~ i ~ ~®c ~~ ~n~ cap=r,ot ~e ~.~ . ~a4~ ~, ~~ ~~ u~=Iish~d wih~o ~ '~_. ~~~` R~. - ~ - „ ~ ~* ~ ~~~ p ~„ written conse~ t~. ~ :.: 4 ~,~ ~ A ,. ~ ~ ~ _i .. s~~ ConocoPhilii p~ ,,- _ ~ r ~~~r ..:~ .~: ~- :. vrs .~ k 3~ ~ ~„ ~'~ ~. ki yr'a., ¢~' • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 2B-13 Run Date: 5/24/2010 May 28, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2B-13 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21138-00 ,. -. 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.barreto@halliburton. com ~ .Y ~' ~~ Date: ~1 Qj ~~ Y Signed: ~, , s • • ~~a~~ 0~ Q~Q~~a /,E.,.~~«~o~..o. Perry Klein Well Integrity Projects ConocoPhillips Alaska, Inc. ~ dA~~~' ",~F ~~, z> ~ ~1"~' P.O. Box 100360 ~` ~` Anchorage, AK 99510 ~ O ~~f Re: Kuparuk River Field, Kuparuk Oil Pool, 2B-13 ~,. Sundry Number: 310-162 Dear Mr. Klein: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. y ~ Chair DATED this Z `day of May, 2010. Encl. ,o tD s'?'~' STATE OF ALASKA ~~ ALAS~IL AND GAS CONSERVATION COMMISSI~ ~,'L APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RE~E~VED MAY 2 5 2010 1. Type of Request: Abandon ~ Plug for Redrill [" F>rrforate New Pool r Repair w ell ~A~s$k I~il~•°SI Suspend r Plug Farforations (- Perforate r Pull Tubing r Anc~nsion ~` Operational Shutdown ['` Re-enter Susp. Well [ Stimulate ~ After casing r Other:SC Welded patch r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r, Exploratory r 184-104 - 3. Address: Siratigraphic r Service r 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-21138-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest property Tine 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No ~~' ~ 2B-13 . 9. Property Designation: . 10. Field/Pool(s): ALK 2581 ADL 0025655 Kuparuk River Field / Kuparuk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Etfective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 7145 6351 Casing Length Size MD ND Burst Collapse CONDUCTOR 74 16 110' 110' na na SURFACE 2769 9.625 2804' 2738' 3520 2020 PRODUCTION 7077 7 7110' 6320' 4980 4320 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 66614-6630,6730-6744,6764-6792 5891-5905,5992-6004,6021-6045 3.5 J-55 6674 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) PACKER - CAMCO'HRP-1-SP' PACKER MD= 6483 ND= 5777 PATCH - 21:5' MERLA TBG PATCH, SET ACROSS GLM #7 SET MD= 6578 ND= 5860 PATCH - 22' MERLA TBG PATCH; SET ACROSS HOLE IN BLAST MD= 6613 ND= 5890 PACKER -BAKER FB1 PACKER MD= 6655 ND= 5927 SAFETY VLV - OTIS 'FMX' (LOCKED OUT 2/5/2004) MD= 1899 ND= 1898 12. Attachments: Descriptan Summary of Proposal ~, 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r E~loratory r Deoelopmentri` Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 5/22/2010 pil ~ Gas ~ WDSPL r Suspended 16. Verbal Approval: Date: WINJ r GINJ r WAG ~ Abandoned Commission Representative: GSTOR r SPLUG r 17. I hereby ~ haf'oregoing is tru nd ect tot best of my knowledge. Contact: Perry Klein / MJ Loveland Pri Name Perrv Klein Title: Well Integrity Projects . ~~ ' Signature ~ Phone: 659-7043 Date ~ Z 2 ~ ~ Commission Use Onl Sundry Number ff ^^ Conditions of approval: Notify Commission so that a representative may witness ~ ~ '' ( W~ nical Integrity Test r Location Clearance a Plug Integrity r BOP Test r Mech ~ ^ Other. _ No-rt L N. S~~-t a'S Q ~~K Subsequent Form Required: ! ~ • 7 Q 1 APPROVED BY ~ ~~~/ Approved by: COMMISSIONER THE COMMISSION Date: n Form 10-403 Re,~ ~$ I G 1 N A L ~~ ~i~.`~ Submit in Duplicate • ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 22, 2010 Mr. Guy Schwartz Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr.Schwartz: Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc., we112B-13, PTD (184-104), gas lift producer, surface casing excavation and repair. Please call me or MJ Loveland at 659-7043 if you have any questions. ~~ Sincerel~~ / - ~_ _-_ _~- e m ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska, Inc. Kuparuk We112B-13 (PTD 184-104) SUNDRY NOTICE 10-403 APPROVAL REQUEST OS-22-10 This application for Sundry approval for Kuparuk we112B-13 is for the repair of a surface casing leak. The well is a gas lifted producer, drilled and cased in Sep /Oct. 1984 then completed 10/21/1984. On 1/29/2010 a surface casing leak was suspected and reported to the AOGCC. On 2/14/2010 diagnostics confirmed the leak which is believed to be near surface and most probably a thread leak in the surface casing mandrel or first collar. With approval, repair of the surface casing will require the following general steps: 1. Shut-in and secure well. Set positive pressure plug and fluid pack the IA as needed to remove all gas. Freeze protect the T and IA. Perform mechanical integrity test and draw down test on tubing plug to verify barrier. 2. Excavate wellhead location. 3. Install nitrogen purge equipment. 4. Cut away the conductor casing and remove cement around surface casing for inspection of suspect leak area. ~ 5. Notify AOGCC Field Inspector of repair operation so they may witness the event. 6. Repair damaged surface casing integrity. Repair options include sleeve patch, seal weld, lap patch, deposition weld and will be determined after inspection of the casing damage. 7. QA/QC the repair welds and MIT-OA to verify integrity 8. Install anti-corrosion coating on exposed surface casing. 9. Patch the conductor and top off the conductor void with cement and corrosion inhibiting sealant. 10. Backfill gravel around the wellhead. 11. Remove plugs and return the well to production. 12. Submit 10-404 report of repair operations to AOGCC. CONDUCTOR, 36110 SAFETY VLV, 1,899 GAS LIFT, 1,939 SURFACE, 35.2,8oa GAS LIFT, 3,677 GAS LIFT, 5,070 GAS LIFT, 5,976 GAS LIFT, 6,423 PBR, 6,465 PACKER, 6,483 PRODUCTION, 6,523 PATCH, 6,576 PRODUCTION, 6,593 IPERF, 6,614-6,630 PATCH, 6,613 PRODUCTION, 6,644 SEAL ASSY, 6,655 PACKER, 6,655 SBE, 6,656 NIPPLE, 6,668 SOS, 6,674 IPERF, 6,730-6,744 CONDUCTOR 16 15.060 36.0 110.0 110.0 62.50 H-40 Casing Description SURFACE String 0... 9 5/8 String ID ... 8.765 Top (ftKB) 35.2 Set Depth (f... S 2,804.4 et Depth (TVD) ... 2,738.0 String Wt... 36.00 String ... J-55 String Top Thrd BTC Casing Description PRODUCTION String 0... 7 String ID ... 6.151 Top (ftKB) 32.7 Set Depth (f... S 7,109.7 et Depth (TVD) ... 6,320.2 String Wt... 26.00 String ... J-55 String Top Thrd BTC Tubin Strin s Tubing Description TUBING String 0... 31/2 String ID ... 2.992 Top (ftKB) 30.4 Set Depth (f... S 6,674.6 et Depth (TVD) ... 5,943.9 String Wt... 9.30 String ... J-55 String Top Thrd EUE8rd Com letion Det ails Top (ftKB) Top Depth (TVD) (ftKB) Top Incl (°) Item Description Comment Nomi... ID (in) 30.4 30.4 0.03 HANGER GREY TUBING HANGER 3.500 1,899.3 1,898.3 8.43 SAFETYVLV OTIS'FMX'(LOCKEDOUT2/5/2004) 2.813 6,464.9 5,762.0 30.27 PBR CAMCO'OEJ' PBR 2.950 6,482.7 5,777.3 30.17 PACKER CAMCO'HRP-I-SP' PACKER 2.875 6,599.4 5,878.5 29.50 BLAST JT 2.992 6,654.6 5,926.5 29.49 SEAL ASSY BAKER LOCATOR w/ PACKER SEAL ASSEMBLY 3.000 6,655.5 5,927.3 29.50 PACKER BAKER F61 PACKER 4.000 6,658.0 5,929.4 29.51 SBE BAKER SEAL BORE EXTENSION 4.000 6,668.3 5,938.4 29.57 NIPPLE CAMCO NO GO'D' NIPPLE 2.750 6,673.8 5,943.3 29.59 SOS CAMCO DE 500 PUMP OUT PLUG / ELMD TTL @ 6668' PER OTIS FLUID LOG 2/8/1985 2.992 Other In Hole ireline retrievable lu s, valves um s, fish etc. Top (ftKB) Top Depth (TVD) (ftKB) Top Incl (°) Description Comment Run Date ID (in) 6,578 5,860.0 29.63 PATCH 21.5' Merla Tbg Patch, Set across GLM #7 set 9/16/1990 9/16/1990 2.375 6,613 5,890.1 29.28 PATCH 22' Merla Tbg Patch; Set across Hole in Blast Joints 9/13/1990 9/13/1990 2.375 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftK8) Btm (TVD) (ftKB) Zone Date Shot Dens (sh••• Type Comment 6,614 6,630 5,891.0 5,905.0 C-4, 2B-13 10/20/1984 12.0 IPERF BLOCKED BY PATCH set 9/13/1990 6,730 6,744 5,992.0 6,004.1 A-4, 2B-13 10/20/1984 4.0 IPERF 4" HJ II; 90 deg. phase 6,764 6,792 6,021.5 6,045.7 A-3, 28-13 10/20/1984 4.0 IPERF 4" HJ II; 90 deg. phase Notes: General & Safe End Date Annotation 2/27/2010 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 Mandrel Details Stn Top (ftKB) Top Depth (TVD) (ftKB) Top Incl (°) Make Model OD lin) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com... 1 1,939.0 1,937.4 9.58 CAMCO KBUG 1 GAS LIFT GLV BK 0.125 1,260.0 11/8/2007 2 3,677.3 3,455.7 35.29 CAMCO KBUG 1 GAS LIFT GLV BK 0.125 2,165.0 11/8/2007 ~ ~ nFO F ~uta ~ ~ s~ n K I Ir, 1 r c I F r_I v K n iSR 1 ZM n 11/R/~nn7 • Page. l of 1 Regg, James B (DOA) ~ 1 ~4- I a4 From: NSK Problem Well Supv [n1617@conocophillips.com] ~J J Sent: Friday, January 29, 2010 2:54 PM `~~g i~~l is To: Schwartz, Guy L (DOA); Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; CPF2 Prod Engrs; CPF2 DS Lead Techs NSK Subject: 2B-13 (PTD #184-104) Report Of Surface Casing Leak Attachments: 26-13 Wellbore Schematic.pdf; 26-13 TIO Plot.pdf "~ Guy/Tom/Jim, ~ Kuparuk gaslifted producer 2B-13 (PTD #184-104) is suspected of having a surface casing leak based upon a failed MITOA in which fluids were returned to surface up the conductor. CPAI intends to perform diagnostics to determin~Tie depth of the leak and repair it if possible. Attached is a schematic and 90 day TIO plot. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 ~~~ ~ ~d ~ l ~,~~ ~ 1 /29/2010 Date 2/1/2010 120 :Date 10!4/2009 1600 1400 1200 1000 .Q 800 600 400 200 0 Oct-09 Annular Communication Surveillance 140 120 100 80 LL d .a 60 40 20 0 • 0 a m 0 U Nov-09 Dec-09 Jan-10 Oct-09 Nov-09 Dec-09 Jan-10 Date C~nocoPhill~ps Alaska, Ir~~. KRU 2B-13 sssv (lass-1soo, OD:5.937) Gas Lift MandrelNalve 1 (1939-1940, Gas Lift MandrelNalve 2 (367a-3679, Gas Lift MandrelNalve 3 (5070-5071, Gas Lift MandrelNalve 5 (6423-6424, SBR (64655466, OD:3.500) PKR ~, (6483-6484, OD:6.151) Production MandrelNalve 6 (65236524, PATCH (65785600, OD:2.765) 26-13 -- - _ __ API: 500292113800 Well T e: PROD An le TS: 30 de 6613 SSSV Type: LOCKED OUT Orig 10/4/1984 Angle @ TD: 30 deg @ 7145 Com letion: Annular Fluid: Last W/O: Rev Reason: C/O OV Reference Lo Ref Lo Date: Last U date: 12/20/2007 Last Ta : 6835 TD: 7145 ftKB ~, rt . Last Tag Date• 1 1/16/2007 Max Hole An le: 36 deg_@ 44 00 _, . , . __ T_____ ,.;~. ~ ng r ng - Cas Descri tfon Size _ To J _ Bottom __ TVD _ Wt Grade Thread CONDUCTOR 16.000 0 110 110 62.50 H-40 SUR. CASING 9.625 0 2804 2738 36.00 J-55 :~~ PROD. CASING 7.000 _ _ 0 _7110 6320 __ 26.0_0 J-_5_5_ Tubin Strin - TUBING Size To Bottom TVD __ _ Wt Grade Thread 3.500 ~- 0 - 6672 5942 9.30 J-55 8RD EUE. . '- Perforations Summary__ _ _ _ - ~ Interval TVD Zone Status Ft SPF Date T e Comment 6614 - 6630 5891 - 5905 C-4 16 12 10/20/1984 IPERF BLOCKED BY PATCH set 9/13/1990 6730 - 6744 5992 - 6004 A-4 14 4 10/20/1984 IPERF 4" HJ II' 90 de hase `}::, ,~ 6764 - 6792 6021 - 6046 A-3 --- _ ___28 4 10/20/1984 - -- IPERF 4" HJ II; 90 deg. phase , Gas Lift Mandrels/Valves _ __ _ -- i St MD TVD Man Mfr Man Type V Mfr V Type T V OD Latch Port TRO Date Run Vlv ~ Cmnt `~ '~ ~- I i i ALL STRINGS St ;~ ~ ,_ 1 1939 1937 Camco KBUG GLV 1.0 BK 0.125 1260 11/8/2007 2 3678 3456 Camco KBUG GLV 1.0 BK 0.125 1265 11/8/2007 3 5070 4590 Camco KBUG GLV 1.0 BK 0.156 1300 11/8!2007 4 5976 5346 Camco KBUG DMY 1.0 BK 0.000 0 11/7/2007 -- -- 5 6423 5726 Camco KBUG OV 1 0 BK 0_._2.50 0 12_/_3_/2007, Pro duction Man drelsNa lves _ _ _ l St MD TVD Man Mfr ___ _ Man Type V Mfr V Type V OD , Laich Port TRO Date Run Vw Cmnt 6 6523 5812 Camco KBUG HFCV 1.0 BKP 0.000 0 11/16/200 7 6593 5873 Camco KBUG PATCH 1.0 BK 0.000 0 9/16/1990 Closed _ 8 6644 591.7 _Camco_ _ KBUG _ ___ _DMY 1.0 _ __ BK 0.000 0 7/27_/1990 Closed Oth er (olu as. eauio.. etc.1 -JEWELRY 6578 5860 PATCH 21.5' Merla Tb Patch, Set across GLM #7 set 9/16/1990 2.375 6613 5890 PATCH 22' Merla Tb Patch' Set across Hole in Blast Joints 9/13/1990 2.375 6650 5923 PKR Baker'FB-1' 4.000 6668 5938 NIP Camco'D' Nioole NO GO 2.750 ~ 6671 ~ 5941 ~ SOS ~ Camco PE-500 I 2.992 I 662 X5942 TTL ELMD 6668' PER OTIS FLUID LOG 2/8/1985 ~ 2.992 ~ PATCH (66135634, OD:2.765) Pert (66145630) ~L PKR (66505651, OD:6.151) TUBING (05672, OD:3.500, ID:2.992) SOS (66715672, OD:3.500) Perf (67305744) Pert (67645792) ,,.`_~ ~, ~~ i Schlumberger -DCS ,~~:~~~~`~ : ~ . ~~. -~ 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth "~~ ~~~ ~~~~ FEB ~ ~ 2aa Well Job # Log Description C..~ NO.4564 Company: Alaska Oil 8~ Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 01 /25/08 26-13 11996584 PRODUCTION PROFILE ~~ ' Jp 01110108 1 1E-112 11994598 INJECTION PROFILE US - g 01/11/08 1 1J-164L1 12005203 MEM INJECTION•PROFILE ad~- ~ ~ U~~ 01122108 1 2M-20 11996596 PRODUCTION PROFILE (g - Q~-( 01/22/08 1 1C-170 11970605 USIT -p 12/02/07 1 2G-06 11994596 PSP MULTI-FINGER CALIPER - 01/10/08 1 3K-102 11994599 MDT ~ - 01114/08 1 1J-127 11994603 INJECTION PROFILE O=.C.. ~O(p•-~(~- 01/21/08 1 2T-21 11839639 RST 1 ~ 08/02/07 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • C~ Cb 2B-13 (PTD 1841040) Failed TIF~ Page 1 of 1 • Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophiliips.comJ ~~~ .1 Sent: Sunday, October 28, 2007 8:05 AM ~ ~~ ~`~ To: Maunder, Thomas E (DOA}; Regg, James B (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: 26-13 (PTD 1841040) Failed TIFL Attachments: 2B-13 schematic.pdf; 2B-13 90 day TIO plot.jpg Tom & Jim, ,/ Gas lifted producer 2B-13 (PTD 1841040) failed a TIFL on 10/27/07 and has been added to the weekly SCP report. The TIO immediately prior to SI for the TIFL was 220/1300/460. A leaking GLV is suspected. Slickline will trouble shoot the tubing leak and repair if possible. ,/ Attached is a schematic and 90 day TIO plot. Please let me know if you have any questions. «26-13 schematic.pdf» «2B-13 90 day TIO plot.jpg» Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Cell Phone (907) 943-1999 Pager (907) 659-7000 pgr. 909 ~~~ ~~~ ~ 2~~~ 11 / 1 /2007 • • ,f,~ KRU 2B-13 ~G+t'~4GC3Phl#~1{~75 A~dS~C~, ~t1C. ..,.., ~2B-13 - ---- -- - _ __ _ API: 500192 i 13tsilu VVelf l e: i'FtuG An le a l S: 311 de w bo t3 SSSV Type: LOCKED OUT Orig 10/4/1984 Angle @ TD: 30 deg @ 7145 sssv (lass-1soo ~= -~~ Com letion: , oDSSS7} , Annular Fluid: Last W/O: Rev Reason: TAG SLM f Reference L Ref Lo Date: Last U date: 10/4/2007 i I Last Ta : 6752 TD: 7145 ftKB 1= Last Taq Date: 9/28/2007 Max Hole Angle: 36 deq a(7 4400 .{ , ~ - ' Casing String -ALL STRINGS _ €i ! Il~carrinfinn I Ci~c _ ~ Tnn I Rnttnm T _ T\/f7 ~ tnn lArorln Thrn~A Gas Lift MandrelNafoe 2 (36783679, Gas Lift MandrelNal~e 3 (5070-5071, Gas Lift MandrelNalve 4 (5976-5977, Gas Lift MandrelNal~e 5 (6423f424, SBR (6465Fi466, OD:3.500) CONDUCTOR 16.000 0 110 110 62.50 H-40 SUR. CASING 9.625 0 2804 2738 36.00 J-55 n I 7110 I 6320 I 26 00 I J-55 I I T dD 'JJt Grade Thraad PKR (64836484, OD:6.151) Production MandrelNalve s (6523f524, PATCH (6578Fi600, OD:2.765} PATCH OD:2.765) ___ Perf .... - (6614~630) ~~~-~~ PKR (6650Fi651, OD:6.151) TUBING (0-6672, OD:3.500, ID:2867) SOS (6671f672, OD:3.500) Pert (6736Fi744) Pert (6764-6792) ~~ ~ I F'KC)L) t_ASING I ZD00 I [~ Tubing String -TUBING F3 ~ Size Tap f [.['nm li ' i_l(1 n ~ ~ I Perforations Summary I e~' I i _~ .k .r I I - i _. ®~ ~ 1 I T--~ --- l -. __ J ~ Interval TVD ZOne StatUS Ft SPF Date T B Comment 6614 - 6630 5891 - 5905 C-4 16 1 2 10/20/1984 IPERF BLOCKED BY PATCH set 9/13/1990 + 6730 - 6744 5992 - 6004 A-4 14 4 10/20/1984 IPERF 4" HJ II; 90 de . hase r . ~ 6764 - 6792 6021 - 6046 A-3 Gas Lift Mandrels/Valves St MU TVD Man Mir Man Type V Mfr 28 4 10/20/1984 IPERF V Type V UD Latch Port 4" HJ II: 90 deq. phase TR© Date Run Vlv Cmnt ''' ~ 1 1939 1937 Camco KBUG DMY 1.0 BK 0.000 0 6/10/1997 3 2 3678 3456 Camco KBUG GLV 1.0 BK 0.156 1318 4/29/2005 3 5070 4590 Camco KBUG GLV 1.0 BK 0.188 1356 4/29/2005 4 5976 5346 Gamco KBUG GLV 1.0 BK 0.188 1352 4/29/2005 5 Pro St 6423 ductio MD 5726 n Man TVD Camco drels/Va Man Mfr KBUG lves Man Type V fdfr OV V Type 1.0 Y OD BK Latch 0.188 Port 0 TRO 4!28/2005 Gate Run Vlv Cmnt 6 6523 5812 Camco KBUG HFCV 1.0 BKP 0.000 0 4/28/2005 7 6593 5873 Camco KBUG PATCH 1.0 BK 0.000 0 9/16/i990 Closed R 6F><t4 5917 Gamr-n Other (plugs, equip., etc De th TVD T e KBUG .) -JEWELRY DMY 1 0 RK n nnn 0 7/2711990 Descn tion Clos?ri iD ' ~ 1899 1898 SSSV Otis'FMX' LOCKED OUT 2/5/2004 2.813 6465 5762 SBR Camco'OEJ' 2.937 6483 5778 PKR Camco 'HRP-I-SP' 2.875 6578 5860 PATCH 21.5' Merla Tb Patch, Set across GLM #7 set 9/16/1990 2.375 6613 5890 PATCH 22' Merla T Patch; Set across Hole in Blast Joints 9/13/1990 2.375 6650 5923 PKR Baker'FB-1' 4.000 fff 6668 5938 NIP Camco'D' Ni le NO GO 2.750 6671 5941 SOS Camco PE-500 2.992 6672 5942 TTL ELMD 6668' PER OTIS FLUID LOG 2/8/1985 2.992 r.. {; 2B-13 (184-104) Failed TIFL4/17/05 ) ) Subject: 2B-13 (184-'104) Failed TIFL4/17/05 From: NSK Problem Well Supv <n1617@conocophillips.com> Date: Sun, 17 Apr 2005 18:01 :21 -0800 To]: tom _ maunder@admin~state.ak.us CC: jim_regg@admìn.state.alcus Tom 28-13 (184-104) failed a TIFL today. TIIIO = 220/1000/900 I added it to the Weekly SCP report for next week. Let me know if you have any questions. MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 SCANNED JUL {) 7 2005 1 of 1 5/10/2005 8:39 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown ~ Pull tubing Alter casing 2. Name of Operator ARCO Alaska, Inc. 3. P. Stimulate X Plugging Perforate __ Repair well Other 4, 5. Type of Well: Development X Exploratory Address Stratigraphic ©. Box 100360, Anchorage, AK 99510 Service Location of well at surface 463' FSL, 155' FEL, Sec. 19, T11N, R9E, UM At top of productive interval 1455' FNL, 1280' FEL, Sec. 19, T11N, R9E, UM At effective depth '1255' FNL, 1335' FFL, Sec. 19, T11N, R9E, UM At total depth 1198' FNL, 1350' FFL, Sec. 19, T11N, R9E, UM 12. Present well condition summary Total Depth: measured 71 4 5 true vertical 6350 feet feet 6. Datum elevation (DF or KB) RKB 125 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2B-13 9. Permit number/approval number 84-104 10. APl number 50-029-21138-00 11. Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) None Effective depth: measured 7 0 2 8 feet true vertical 6249 feet Junk (measured) None Casing Length Size Structural Conductor 8 0' 1 6" Surface 2 7 6 9' 9 - 5 / 8" Intermediate Production 7077' 7" Liner Perforation depth: measured 6614'-6630', true vertical 5890'-5904', Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 6666' Packers and SSSV (type and measured depth) Pkr: Cemented Measured depth True vertical depth 224 Sx CS II 1 1 0' 1 1 0' 800 Sx CS III & 2804' 2737' 250 Sx CS II 320 Sx Class G & 71 1 0' 6 2 3 3' 250 Sx AS I 6730'-6744', 6764'-6792' 5991'-6003', 6021'-6045' Baker FB-1 @ 6650'; SSSV: Otis FMX @ 1899' 13. Stimulation or cement squeeze summary Alaska 0il .& L~c,s 00ns. G.0.[~¢ss~''' 14. Refracture "A" sands on 6/28/96 Intervals treated (measured) 6730'-6744', 6764'-6792' 0RI61NAL Treatment description including volumes used and final pressure Pumped 228.5 M lbs 20/40, 12/18, & 10/14 ceramic proppant into formation, fp was 4070 psi. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Pdor to well operation 1 1 2 5 1151 266 1350 174 Subsequent to operation 1 9 0 9 2245 559 1385 183 15. Attachments Copies bf Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SignedForm 1~15/-~8/~ Title Wells Superintendent Date -4, - 9 ° 9 ? SUBMIT IN DUPLICATE ARCO 'Alaska, Inc. . -, KUPARUK RIVER UNIT '' WELL SERVICE REPORT ~ K1(2B-13(W4-6)) WELL JOB SCOPE JOB NUMBER 2B-13 FRAC, FRAC SUPPORT 0624961858.5 DATE DAILY WORK UNIT NUMBER 06/28/96 PUMP "A" SANDS RE-FRAC DAY OPERATION COMPLETE ~ SUCCESSFUL KEY PERSON SUPERVISOR 2 (~D Yes O NoI (~) Yes O No DS-YOAKUM JOHNS FIELD AFC# CC# DALLY COST ACCUM COST ESTIMATE KM1263 230DS28BL $148,262 $154,949 Initial TbCl Press Final Tb_a Press Initial Inner Ann Final Inner Adh I Initial Outer An~ 340 PSI 1600 PSI: 3500 PSI 1100 PSI! 100 PSII 100 PSI DAILY SUMMARY PUMPED "A" SANDS RE-FRAC , PLACED 228,500 # PROPPANT IN FORMATION. 19, 000# 20/40 , 201,000# 12/18 AND 9,485# 10/14. . 520# 10/.1.4 LEFT IN PIPE. ,. TIME LOG ENTRY 07:00 MIRU DOWELL FRAC EQUIP. .. 08:00 HELD ONSITE SAFETY MEETING 08:45 PRESSURE TEST SURFACE LINES TO 7450 PSI 08:55 SET TREE SAVER, INITIAL WHP WAS 340 PSI 09:10 PERFQRM Q.C. ON FLUIDS, RUN 4 GAL PER THOUSAND ACTIVATOR. 09:10 START PUMPING BREAK DOWN & SCOUR STAGE AT 15 BPM, TOTAL 215 BBLS FLUIDS INCLUDING 2,000# 20/40 SCOUR PROPPANT. 3406 PSI. SHUT DOWN FOR ISIP 1671 PSI. 09:56 PUMPED 165 BBLS DATA FRAC STAGE FOR CLOSURE PRESSURE CAL. 5 TO 15 BPM 3049 PSI. SHUT DOWN FOR ISIP 1621 PSI. 10:54 PUMPED 285 BBLS PAD. 15 BPM AND 3333 PSI. 11:20 PUMPED PROPPANT STAGES OF 20/40 (19,000 #), 12/18 (201,000#) AND 10/14 (9,485#) W/50# GEL SYSTEM AND 2PPA TO 10 PPA. 12:32 FLUSHED TO COMPLETION WITH 45 BBLS DIESEL IN TUBING. MAX TREAT PRESSURE 4070#. 10 PPA 10/14 PROPPANT ON PERFS. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $450.00 APC $3,100.00 $4,675.00 DOWELL $140,955.00 $140,955.00 HALLIBURTON $0.00 $4,662.00 LR-I-LE RED $4,207.00 $4,207.00 TOTAL FIELD ESTIMATE $148,262.00 $154,949.00 STATE OF ALASKA AI.Az3KA OIL AND C_¢,S CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate ,~ Plugging Perforate _ Repair well X Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5, Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1463' FSL, 597' FEL, Sec. 19, T11N, R9E, UM At top of productive interval 3825' FSL, 1280' FEL, Sec. 19, T11N, At effective depth 3896' FSL, 1300' FEL, Sec. 19, T11N, At total depth 4082' FSL, 1350' FEL, Sec. 19, T11N, R9E, UM R9E, UM R9E, UM 12. Present well condition summary Total Depth: measured 71 4 5' true vertical 6350' feet Plugs (measured) feet 6. Datum elevation (DF or KB) 125' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 2B-13 feet 9. Permit number/approval number 84-104 10. APl number 50-029-21138 11. Field/Pool Kuparuk River Oil Pool Effective depth' measured 7028' true vertical 6249' feet Junk (measured) feet Casing Length Size Structural Conductor 1 1 0' I 6" Surface 2 8 0 4' 9 5/8" Intermediate Production 7710' 7" Liner Perforation depth: measured 6614' - 6630' true vertical 5891' - 5905', Tubing (size, grade, and measured depth) Cemented 224 Sx CS II 800 Sx CS III & 250 Sx Class G 320 Sx Class G & 250 Sx CS I (C Sand), 6730' - 6792' 5992' - 6046' Measured depth True vertical depth 110' 110' 2804' 2737' 7110' (A Sand) 6320' RE, F IVED 3 1/2" J-55 EUE, 9.3 lb/fi, set @ 6666' Packers and SSSV (type and measured depth) Packers: CAMCO HRP-1SP 6477', BAKER FB-1 6650', OTIS FMX SSSV ~ 1894' 13. Stimulation or cement squeeze summary Repair tubing with tubing patch. Intervals treated (measured) 6613'-6634' and 6578'-6600' MD. Treatment description including volumes used and final pressure 14. OEO 11 199( Aias~ 0it & Gas Cons. Oom~ss~Ot~ 'Af~chorage Set a tubing patche @ blast joints 6613'-6634 MD and @ C Sand GLM 6578'-6600' MD. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1394 1453 4 1700 130 Subsequent to operation 1394 1453 4 1700 130 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Water Injector B Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 09/12/90 Title SUBMIT IN DUPLICATE WELL SERVICE REPORT i ABCO.Alaska, I n~--. Subsidiary of Atlantic Richfield Comp. WELL PB.~c~ CONTRACTOR REMARKS T~L~DY~J~ i FIELD - DISTRICT - STATE IOPERATION AT REPORT TIME DAYS , DATE ~ ! q-(5--qc I D~?TN Lo(.ll. Tici2 (~ ~[o3q- I~, /~,~o /mo ~ u',," 7"0 i93o 7'-.,C.;~,0 ~ 7'-,q-G PUM/~ ouT' ~t:oG To 7'/g /~/ Na~ka Oil & aas l-"] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ARCO Alaska, In,~ {~ Subsmdiary of Atlantic Richfield Comps- WELL SERVICE REPORI WELL PBDT CONTRACTOR HL5 f~E'i~LA FIELD · DISTRICT- STATE iDAYS DATE I i c1.-10-9o OPERATION AT REPORT TIME REMARKS ~:~T; /¢5'73 =o~ IOZ~' ~[H ~/CCc T~J O,U& f:~TCg 4- t~ldtJ,~d& Iilo P.o~J TJE I~J LO& r~qO0 ~ (~300 'r-oo~ 113o l'~,O~ TI~ lid Lo~, ~0o ~' ~>3o0 od p ~P'r ~t R '¢E!VEP DEC ] I 1990 Alaska Oil & Gas Cons. t;ommission Anchorage [-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather ' ITemP'Report °F Chilm Factor J VismbilitY0F miles Iwind ve~' Subsidiary of Atlantic Richfield Compa AR, CO Alaska, Inc~ ~ WELL 2_.BI3 PBDT 7oz8 CONTRACTOR PI5 H fi~. veco G,~u..~.Go 5 FIELD - DISTRICT- STATE OPERATION AT REPORT TIME CO~Oc~'re WELL SERVICE REPORT REMARKS qr.: ¢ os'r I Oo 3 7_,5' Zl~3 l~'Ff,,~cu~ A SA~Jp I o.~o G, ¢ F~Ac FL. UJO.~ - A-OK I%~" 13~o 5~,~P ~ TuR~UE UUtT' o'r'Hk-'~ uJOuU0U't' &TA~,T ~3~5 oP~ 1320 ,5/...~ ~Cc I~P " 15oo ~gv~o 5+~¢ 8~ 14, ~usk- .gr~R~6-~J RECEIVED 1 1 199~_ Cons. - ct~e~i ~u~,k, ~bbl~ ,, ,, 14, 3o5 ~zl,e OU'(". I t - [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather .. J Temp. Report oF Chill Fact°r0F J Visibility miles JWind Vel. STATE OF ALASKA ~ OIL AND GAS CONSERVATION COMMI,.~o~ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate X Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1463' FSL, 597' FEL, Sec. 19, T11N, R9E, UM At top of productive interval 3825' FSL, 1280' FEL, Sec. 19, T11N, R9E, UM At effective depth 3896' FSL, 1300' FEL, Sec. 19, T11N, R9E, UM At total depth 4082' FSL, 1350' FEL, Sec. 19, T11N, R9E, UM Present well condition summary Total Depth: measured 71 4 5' true vertical 635 0' Effective depth: measured 7 0 2 8' true vertical 62 4 9' Casing Length Size Structural Conductor 1 1 0' 1 6" Surface 28 0 4' 9 5/8" Intermediate Production 71 1 0' 7" Liner Perforation depth: measured 6. Datum elevation (DF or KB) RKB 125 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2B-13 9. Permit number 84-104 10. APl number 5o-029-21 138 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 12. feet feet feet feet Plugs (measured) Junk (measured) ORIGJNA. Cemented Measured depth True vertical depth 224 Sx CS II 1 10' 1 1 0' 800 Sx CS III & 2804' 2737' 250 Sx CS II 320 Sx Class G & 71 1 0' 6 3 2 0' 250 Sx CS I 6614'-6630' (C Sand), 6730'-6792' (A Sand) MD true vertical 5891'-5905', 5992'-6046' TVD Tubing (size, grade, and measured depth 3 1/2" J-55 EUE, 9.3 Ib/ft, set @ 6666' Packers and SSSV (type and measured depth) Packers: CAMCO HRP-1SP 6477', BAKER FB-1 6650', OTIS FMX SSSV @ 1894' 13. Attachments Description summary of proposal _ Detailed operation program X RECEIV-EB Refrac A Sand with 60,700 lbs of 16/20 and 12/18 mesh carbolite. (Procedure and Wellbore schematic attached). 14. Estimated date for commencing operation July, 1990 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas __ Suspended Service J17. I herebt/ certi[v tl~t the foregoing is true and correct to the best of my knowledge. Signed "~~,- ~), ~'~'~ - Title Sr. Operations Engineer FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity B BOP Test_ Location clearance m Mechanical Integrity Test_ Subsequent form require Approved by the order of Commission Form 10-403 Rev 5/03/89 Origlnal Signed l~y David W, Johnston 10-Aft~¥ Commissioner Approved Copy Returned .'3, I lqo IApproval No. SUBMIT IN TRIPLICATE BOP sketch ATTACHMENT 1 KUPARUK WELL 2B-13 A SAND FRACTURE PUMP SCHEDULE 7/23/90 STAGE FLUID CLEAN VOLUME PUMP RATE PROP. CONC. PROPPANT PROPPANT Wq' DIRTY VOLUME HIT PERFS DESCRIPTION BBLS BPM ' PPG DESCRIPTION LBS STG/CUM BBLS I GW PRE-PAD 150.0 25 0 - - 0 1 50 / 150 60 2 Slick Diesel Preflush 60.0 25 0 60/210 210 ............................................. SHUT DOWN FOR ISIP, FLOW METER CALIBRATION .................................................. 3 GWPAD 410.0 25 0 - - 0 410/620 270 4 GW w/2 PPG 27.6 25 2 16/20 M CARBO-LITE 2316 30/650 680 5 GW wi4 PPG 38.3 25 4 16/20 M CARBO-LITE 6427 45/ 695 710 6 GW wi6 PPG 43.5 25 6 16/20 M CARBO-LITE 10961 55 ! 750 755 7 GW w/8 PPG 44.4 25 8 16/20 M CARBO-LITE . 14905 60/810 810 8 GW w/10 PPG 34.7 25 1 0 16/20 M CARBO-LITE 14576 50/860 870 9 GW w/12 PPG 22.9 25 1 2 12/18 M CARBO-LITE 11538 35 / 895 920 I 0 SLICK DIESEL FLUSH 58.0 +SV 25 0 TOTAL DIESEL ADDED TO FRAC STAGES = 31.3 BBLS(Pads + 2 & 4 ppg Stages) 16/20 M CARBO-LITE 49,185 LBS TOTAL GELLED WATER = 740.0 BBLS (excluding diesel) 12/18 M CARBO-LITE 11538 LBS TOTAL GELLED FLUID = 771.3 BBLS TOTAL Proppant 60,723 LBS TOTAL SLICK DIESEL -- 118.0 BBLS +SV NOTES: Stages I & 3 are Gelled Water with 40 lbs/1000 gal silica flour and enough breaker for a 6 hour break. Stage 2 is a Diesel Preflush prior to ISIP shutdown to provide an easier startup. Stage 4 through 9 are Gelled Water with 6 hour breaker WITHOUT silica flour. Stages 1 through 5, excluding Stage 2, will also contain 5% Arctic Diesel by volume for additional fluid loss control. Stage 10 should include a volume adjustment for surface equipment between the wellhead and densimeter. This job is intentionally underflushed by 2 bbls. The blender tub should be bypassed at flush. All fluids should be maintained at 100° F on the surface. ,~;~Recommended maximum surface treating pressure is 6000 psi with 3500 psi on the backside. ~.,,,/If surface pressure increases, reduce treating rate to determine cause of pressure increase. Maintain reduced rate, if necessary. . Messrs Sloan and Kralick July 24, .1990 Page 4 Attachment 2 Kuparuk Well 2B-13 'A' Sand Re-Fracture Procedure Cost Tracking AFE #K81085 1. MIRU Slickline unit. Tag bottom. . Replace GLV's at 1934', 3672', 5970', and 6417' with DV's. Replace CV's at 6517', 6587', and 6639' with DV's. Note that the Mandrel at 5064' is dummied. *Fill was tagged at 6891' on 7/20/90. 3. Fill annulus with diesel and pressure test. 4. Set standing valve in Camco 'D' nipple at 6663' MD-RKB. standing valve. RDMO Slickline unit. Pressure test the tubing. Pull 5. Perform A Sand only production tests. . RU fracture equipment. Install "Tree Saver". Pressure up 7" annulus to 3500 psi. , , Carry out all fluid quality control procedures (Onsite Operations Engineer). Obtain a sample of the proppant and of the gelled diesel with breaker. Check the proppant for fines. Record proppant weight prior to pumping. After the fracture stimulation, verify and record weight of remaining proppant. Obtain samples from pad and slurry stages while pumping. Pump the 150 Bbl pre-pad at 25 BPM. Shut down and determine the ISIP. The A Sand was perforated with 168 shots, 4 spf with an SOS 4" Hyper-Jet. Pump fracture treatment per the attached schedule. Record the 2, 5, 10, and 15 minute pressures following the ISIP. Expected wellhead treating pressure: WHTPE = 3850 psig Fracture Gradient = 0.76 psi/ft (5990' TVD) Frac Fluid Gradient = 0.438 psi/ft Tubing Friction = 290 psi/1000 ft @ 25 BPM (6666' MD) *If excessive treating pressures are experienced, try reducing the rate in small increments adjusting additive rates as appropriate. The maximum recommended treating pressure is 6000 psi based on analysis of tubing strength and PBR type. 8. Rig down fracture stimulation equipment. Follow attached flowback schedule. KUPARUK WELL 2B-13 APl #: SPUD DATE: ORIGINAL RKB: 500292113800 ADL LEASE: 25655 PERMIT #: 09/28/84 COMPLETION DATE: 10/21/~4 WORKOVER DATE: SURFACE LOCATION: 1463'FSL,597'FEL,SEC19,T11N,R9E TOP OF KUPARUK: 3825'FSL,1280'FEL, SEC19,T11N,R9E TD LOCATION: 4082'FSL,1350'FEL, SEC19,T11N,R9E All depths are MD-RKB to ~p of equipment unless otf~erwise noted 125 TUBING SPOOL: PAD ELEVATION: WELLTYPE: PRODUCER CASING and TUBING DETAILS SIZE WEIGHT GRADE DEPTH 16' 62.54t H-40 110 9.625' 36# J-55 2804 7' 26# J-55 7110 3.5' 9.3~ J-55 6666 LINER DETAILS SIZE WEIGHT GRADE TOP BTM TUBING JEWELRY ITEM TYPE ID DEPTH sssv ohs FMX 2.s 3' SBR CAMCO F,..~e; ~.-~ - ~_OE'~') 6459 ~R C~CO ~ ~ P- I ~P ~ PKR B~ER ~1 66~ N~ C~CO 'D' NIPPLE 2.75' 66~ SH~ C~CO p~- ~ 66~ 84-104 · GAS LIFT and FLOW INFORMATION VALVE STN DEPTH 1 1934 2 3672 3 5064 4 5970 5 6417 6 6517 7 6587 8 6639 PORT MANDREL SIZE SIZE ~A~c_o ~ ~0 1.0" .1875 :' ' ' 1.0" .1875 " " 1,0' DV .... 1.0" .2500 " 1.0' ,2500 1.0' FO ~' " 1.0" FO ' ' 1.0" FO INTERVAL 6614-6630 6730-6744 6764-6792 PERFORATION DATA ZONE FT SPF PHASE COMMENTS C 16 12 A 14 4 5~ ~{" A 28 4 ~os ~" H~ MISC. DATA DESCRIPTION KICK OFF POINT: MAX HOLE ANGLE: 35 deg HOLE ANGLE THRU KUP: 30 deg LAST TAG DATE: '3 I:Ze Iqo RATHOLE: 66q I ft FISH/OBSTRUCTION: PBTD: PBTDSS: DEPTH 1600 7O28 6124 REVISION DATE: 06/03/87 REASON: RUN GLV'S SUNDRY NOTICE - WELL 2B-13 NO BOP'S WILL BE UTILIZED DURING THIS PROCEDURE. BOTTOM HOLE PRESSURE (6200' SS) - 3000 PSI NO WORKOVER FLUID WILL BE USED DURING THIS PROCESS. ARCO Alaska, inr-~ Post Office .~ox 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DATS: 09-05-85 TkANSNITTAL NO: 5332 bLETUKN TO: TR3YNSMITTED RECEIPT AND SEQUENCE OF ARCO ALASKA, INC. KUPARUK_ OPERATIONS ENGINEERING RECORDS CLERK A%'O-1115B P.O. BOX 100360 ANCnUKAGE, AK 99510 : HEREWITt{ ARE THE FOLLO%{ING ITEHS. kETUPJ{ ONE SIGNED COPY OF THIS EVENTS- PRESSURE DATA 1H-3 J PBU 03-07-85 2A-l--' 'C' SAND PBU 08-03-85 2B-13-' 'C' SAND PBU 08-01-85 2C-U 'A' SAND PBU 08-16-85 2V-2 ' 'A' SAND PBU 07-27-85 2V-5 ~ 'A' SAND PBU 06-25-85 PLEASE ACKNOWLEDGE TRANSMITTAL. SEQUENCE OF EVENTS FR~)£,J WELL SERVICE REPORTS/PRESSUKE la-8~' bBHP & HISC. 08-22-85 la-5 PBU & MISC. 08-14-85 la-3'~''- PBU 08-12-85 la- 3-'- PBU 08-11-85 lB-2-~ 'C' SAND P~U 08-05-85 lB-2---- 'C' SAND PBU 08-0.6-85 lB-5 ~ STATIC TEMP.LOG 08-15-d5 1E-21~ RUN BHP & MISC. 08-03-85 1F-5 PBU 'A' & 'C' bAND {ISLTD) U8-18-85 1F-5/ PBU 08-17-85 1G-15~ 'C' SAND PBU 08-10-85 1G-15'~ 'A' SAND PBU & MISC. 08-06-85 1G-15/ 'C' SAND PBU 08-09-85 1R-10..-"BHP & MISC. 08-15-~5 1R-9./ BiiP& MIbC. 08-15-85 1R-12 ~ BHP & MISC. 08-19-85 2A-1/ 'C' SAND PBU 08-04-85 2A-1'/ 'A' SAND BHP 0S-04-85 2A-1~- 'C' SAND PBU 08-03-85 2A-13..- BSP & MISC. 08-25-85 2B-13~" 'A' SAND BRP 0~-02-85 2B-13-' 'C' SAND PBU 08-02-85 2B-13--' DATA FROM ~HP SURVEY 08-03-85 2B-13-~ 'C' SAND PbU 08-01-85 2C-8/ PBU 08-17-85 2G-16" PBU 08-17-85 2G-16'/ PBU 08-1~-85 t<LCEIPT ACKNOWLEDGED: BPAE DRILLING B. CURRIER L. JOHNS?ON CHEVRON ['zUDIL D & M NbK CLERK DISTRIBUTION: W. PAStiER EXXON DATA *PLEASE NOTE--DISTRIB- UTION CONTINUED ON NEXT PAGE. P~ILLIP~ OIL UNION ""~ J. ~'I'~'IE LL K. TULIN/VAULT ARCO Alaska, Inc. is a Subsidiary of AttanticRichfieldCompany ARCO Alaska, In~lI Post OfficL~l~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DAT~:09-05-85 TkANSMITTAL NO:5332 PJ~TURN TO: TRANSMITTED kECEIPT AND SEQUENCE OF 1R.-3-" PBU 2A-l--- 'C' 2B-13~ 'C' 2C-~ 'A' 2V-2 - 'A' 2V-5 ~ 'A' ARCO ALASKA, INC. KUPARUK_OPERATIONS RECORDS CLEkK A~O-1115B P.O. BOX 100360 ANC~OKAGE, AK 99510 HERE~ITtf ARE THE kETU~40NL SIGNED EVENTS PRESSUR~ DATA ENGINEERING FOLL~{ING IT~JS. PLEASE ACKNOWLEDGE COPY OF THIS TRANSMITTAL· SAND PBU SAND PBU SAND PBU SAND PBU SAND PBU 03.07-85 08T03-85 08-01-85 .~ 08-16-85 07-27-85 06-25-85 SEQUENCE OF EVENTS FROM WELL lA-8'~ bBHP & MISC. lA-5 PBU & MISC. lA-3/ PBU lA-3-- PBU lB-2-- 'C' SAND PBU lB-2--- 'C' SAND PBU lB-5 -~'- ~TATIC TEMP.LOG 1E-21~ RUN BHP & MISC. 1F-5 PBU 'A' & 'C' b~qD 1G-15~- 'C' SAND PBU 1G-15~ 'A' ~AND PBU & MISC. 1G-15/ 'C' SAND PBU 1R-10~BHP & MISC. 1R-9/ Blip & MISC. 1R-12 ~ BHP & MISC. 2A-i-'j~ 'C' SAND PBU 2A-1~ 'A' SAND BHP 2A-1~ 'C' SAND PBU 2A-13~ BHP & MISC. 2B-13~ 'A' SAND BRP 2B-13~ 'C' SAND PBU 2B-13~ DATA FROM 2B-13~- 'C' SAND PbU 2C-8"PBU 2G-16~ PBb 2G-16/ PBU RLC~IPT ACKNOWLEDGED: BPAE B. ~URRIER CHEVRON D & M SURVEY D~ILLING L. JOHNSTON hbK CLERK SERVICE 'REPORTS/PRESSURt;~' DATA 08-22-~5 08-14-85 08-12-~5 0~-11-85 0~-05-~5 08-06-85 08-15-~ 85 08-03-85 { ISLTD) 0~-18-~5 08-17-85 08-. iO.-B 5' ~08-06-85 08-09.-85 08-15-85 08-15-85 0~-19-85 08-04-85 0~-04-85 O8-03-85 08-25-85 08-02-85 .:¢9 08-02-85 08-03-85 08-01-85 08-17-B5 *PLEASE NOTE--DISTRIB- 08-17-85 UTION CONTINUKD ON DATE: EXXON SOHIO PI~ILLIPS (JIL UNION ~ 6~a~ ~-~. ' J ka'~'~,lE h L K. TULIN/VAULT '~"~c'.',,:~....,. · ..... ~."0; ARCO Alaska. inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, In(. Post Office t:3ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-21-85 TRANSMITTAL NO: 5296 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HEREWITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND RETU~q ONE SIGNED COPY OF THIS TRANSMITTAL. SEQUENCE OF EVENTS FROM WELL SERVICE REPORTS PRESSURE DATA '-~lC-4'v 07-23-85 '-' 1C-5 ~ 07-29-85 '~1C-5,~- 07-30-85 "~1C-6 ~ 07-25-85 "'~iC- 6 ~' 07-24~85 ~lD-8 -- 07-30-85 --~ 1H-3~ 07-30-85 ----1R-5 07-05-85 ----1~{- 6 07-06-85 ~" 1R- 8 ~ 07-U~-85 1Y-10- 07-27-85 1Y-11-- 07-28-85 2A-2 .- 07-04-85 2B- 13' 07-30-85 2U-14' 06-30-85 2U-14 .... 07-01-85 2U-15- 07-08-85 2V-2 07-27-85 2V-2-- 07-28-85 2W-7- 07-26-85 ~2W-7 ~ 07-27-85 2X-15~ 07-09-85 2X-15 ~ 07-04-85 2Z-1' 07-05-85 ~2Z-6- U4-08-85 ~3B-7 ~ 06-27-85 3B-8~ 06-28-85 3B-8-~ 06-27-85 '~ 3B-9 / 07-18-85 3B-11 07-20-85 3B-12' 07-21-85 3C-11 ~ 07-29-85 STATIC BHP PBU PBU STATIC BHP STATIC BHP STATIC BHP STATIC BHP DHP & MISC. BHP & MISC. STATIC BHP & ~,~ISC. STATIC BHP END OF PBU 'C' SAND STATIC BHP PRESSUkE DATA 'A' SAND PBU 'A' SAND PBU PRESSURE TEST & HISC. 'A' SAND PBU 'A' SAND PBU 'A' SAND ONLY PBU 'A' SAND PBU FLO%~ING BHP & FLUID I.D. FLOWING BHP & TEMPERATURE BHP SURVEY & MISC. STATIC BHP STATIC BHP & MISC. STATIC BHP & MISC. BHP & MISC. STATIC BHP & MISC. BHP SURVEY & MISC. STATIC BHP & MISC. STATIC BHP ~ MISC. RECEIPT ACKNOWLEDGED: BpA~* B. CURRIER CHEVRON* D & M* DISTRIBUTION: DKILLING W. PASHER L. JOHNSTON EXXON HOBIL* PHILLIPS OIL* NSK CLERK J. RATRMELL* - ARCO Alaska. Inc. is a Subsidiary o! AtlanlicRichfieldCompany CAMCO DRESSER ATLAS DRESSER ATLAS CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO DRESSER ATLAS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS CAMCO CAMCO OTIS CAMCO CAMCO CAMCO CAMCO ~ · ~U~N/VAU~ ARCO Alaska, Inc. Post Office F.. ~.,100360 Anchorage, Aiaska 99510-0360 Telephone 907 276 1215 RETURN TO: DATE: 08-16-~5 TRANSMITTAL NO: 5267 ARCO ALASKA, INC. KUPA~{UK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B, P.O. BOX 100360 ANCHORAGE, AK 99510 · RANSMITTED HEREWITH ARE ~LECEIPT AND KETUF~4 ONE ?RESSURE FINALS DRESSER ATLAS 1-C-5 PBU · 07-29-85 LC-9 TUBING PRESSURE 07-24-85 !G-15 FLOWING PRESSURE GRADIENT 07-30-85 LY-11 FLOWING PRESSURE & PBU 07-28-85 ~A-1 P~U 08-3/4-85 lB-13 PBU 0~-01-85 /U-1 FLOWING BOTTOMHOLE PRESSURE 08-04-85 .. THE FOLLOWING ITE/4S. PLEASE ACKNOWLEDGE SIGNED COPY OF THIS TRANSMITTAL. ~CEIPT ACKNOWLEDGED: AR* CURRIER EVRON* & M* DISTRIBUTION: DRILLING W. PASHER L. JOHNSTON EXXON MOBIL* PHILLIPS OIL* NSK CLERK J. RATHMELL* STAT~ OF ALASKA* · 'SOH I O* UNION* K.TULIN/VAULT ARCO Alaska, Inc. Post Office Box ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 11, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Well Completion Reports Dear Mr. Chatterton' Enclosed are Well Completion Reports for the following wells' If you 2B-13 2B-14 2C-9 2C-12 2Z-4 Prudhoe Bay State #1 have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU9/L50 Enclosures RECEIVED JUN ~ -~:, _t~-~ Alaska 0ii & 6~S COilS. Conimi:~ston Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE Of ALASKA ..... ALASKA£ AND GAS CONSERVATION CO; IlSSION WI LL C_ MPL_ TION OR RECOMPLETION REPORT AND LOG Classification of Service Well 1. Status of Well OIL [~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-104 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21138 4. Location of well at surface 9. Unit or Lease Name 1463' FSL, 597' FEL, Sec.19, T11N, RgE, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 3825' FSL, 1280' FEL, Sec.19, TllN, RgE, UM 2B-13 At Total Depth 11. Field and Pool 4082' FSL, 1350' FEL, Sec.19, TllN, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 125' RKBJ ADL 25655 ALK 2581 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 09/28/84 10/03/84 10/21/84I N/A feet MS LI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+l"VD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7145'MD,6350'TVD 7028'MD,6249'TVD YES [~[ NO []I 1899 feet MD 1500' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/(;R/$P, Ca]/FDC/CNL, (;yro((;CT), CBL/VDL/(;R, Temp/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" 224 sx Cold S~; II 9-5/8" 36.0# J-55 Surf 2804' 12-1/4" 800 sx CS Ill & 250 sx CS II 7" 26.0# J-55 Surf 7110' 8-1/2" 320 sx Class G & 250 s~ CS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6792' - 6764' 3-1/2" 6672' 6650' & 6483' 6744' - 6730' w/4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6630' - 6614' w/12 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6644' - 6646' 200 sx Class G For fr~. ~nfn -~e' attached Adde.n. dum dated 5/')/85. · 27. N/A PRODUCTION TEST Date First Production ] Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested i PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED ~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECEIVED '~o~r~[ JUN 2 Alaska Oil & Gas Cons Anci':oraga Form 10-407 GRUg/WC35 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE : NAME Include inte~al tested, pressure data, all fluids r~over~ and gravity, . . . · . . MEAS._DEPTH TRUE VERT:'DEP~H, ~,~GOR and time of each phase.. :,~,,-~,~ . ............... ~ .... ~ .... ; ........... ; .............................................. . ............ · ~?':~ r ;-::?'~ .~[ ~ . . ' ~ ,. Top Upper Sand 66~[,,-. 5890~ N/A .~,-~ ' '~s~ U~per Sand T;66~2,-;::~ :; '~ ...... 5906' ................ ' ............. : Top L~er Sand ~:,~ :~;-~]0~~ n:- 5969~_ . . ':', :,L. p:z, ,~,;~_:~-dri~.;;. ~se E~wer "san~..:~? -~-6862 ~ - : -:- -'6i 05~- '~ ......... : ........... ·" _. '~. ~ . . . · .. , . . . ........... . .~; ,_ ',., ~.. · . ~:., ~;~::<' : ~ _ . . : ';. - .; ~i ' .- . [ . .'~ ~:-, ' ,"~.F ,..:....;.. ;.', ,: .,,?;x, '.... . . ' -. . _~ [.' .. . ~. '. · . - .~ .- .. . ; . .... . j ~ · F'~ ~ ~ . t.", _: ': ',: t -- F '~ ~ ' ~.. .' . . . . . . ..... . . , . . . . . 31. LIST OF A~AOHMENTS : ,:: ~":,2 "'.: ....... ~u': '.~;~ :' ' , . . . . . add.,d,m ~ -. ,,,,; ..... , .... .. ., ,_,, ., --. .- -, _ . --.~ ~-, . 32. I hereby ceKtify_that the foregoing is true and Correct to the best of my knowledge ;, ..: , ,, .- ~ . ;- ,. ,., .; , :'.~, : . . . . . Signed & ~ ~~ Title .Associate Eng~.ee~ Date // 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 l: Classification of Service Wells' .Gas.. injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production frOm more than one interval (multiple completion), so state in item 16, and in item 24 show the produCing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be Separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ADDENDUM WELL: 10/04/84 10/08/84 3/25/85 4/03/85 4/04/85 2B-13 Arctic Pak w/250 sx CS I, followed by 58 bbls Arctic Pak. Rn CBL/VDL/GR f/7020'-5000' WLM. Rn GCT gyro f/6974'-surf. Arctic Pak w/250 sx AS, followed by 53 bbls Arctic Pak. Frac well in 8 stages w/268 bbls gelled diesel, 750# 100 mesh & 11,300# 20/40 mesh. Rn Temp/CCL log f/6930'-6400'. Rn Temp/CCL log f/6930'-6400'. Dr i 11 {n~sup e-r~n t end ent JUN 1 2 1985 A(aska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. ~ ' Post Office Bux 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 21, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2B-13 Dear Mr. Chatterton' Enclosed is an addendum to the 2B-13 Well History to include with the Well Completion Report, dated 12/05/84. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU4/L171 Enclosure RECEIVED B 2 5 1985 Gas Cons. C0mmlsslat Anchorage ARCO Alaska, Inc. is s Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office ,.-'x 360 Anchornge, Alaska 99510 Telephone 907 2?7 5637 RETURN TO: Date: 1/31/85 Transmittal No: 5014 PAGE 1 of 3 ARCO ALASKA, INC. ATTN: Records Clerk ATO-11t5B P.O. Box 100360 Anchorage, AK 99510 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH FINALS Schlumberger 0 ~ensity Neutron "Poro" / " ". " "Raw" 10/16/84 Run 1 10/16/84 " 7100 - 7733 2"/5" 7100 - 7733 2"/5" " DILYSFL/GR 10/16/84 " 3276- 7758' 2"/5" " BHCS/GR 10/16/84 " 7100- 7759 2"/5" " CPL Cyberlook 10/16/84 " 7100 - 7700 CPL Cyberlook " Density Neutron "Poro" ~t Tt " "Raw" ,, DiL_sFL/GR 10/03/84 Run 1 _ 10/03/84 " 10/03/84 " 10/03/84 " 6400 - 7050 6400 - 7048 2"/5" 6400..- 7048 2"/5" 2805 - 7074 2"/5" ~1~.2D-3 CPL Cyberlook '/' " Density Neutron "Poro" 10/07/84 Run 1 10/07/84 " 7200 - 7710 7200 - 7878 2"/5" II II " "Raw" 10/07/84 " 7200 - 7878 2"/5" " DIL_SFL/CR 10/08/84 " 3624 - 7910 2"/5" /cat Receipt Acknowledged: B. Currier BPAE Chevron DISTRIBUTION Drilling W. Pasher fGeology~ ' G. Phillips Mobil Phillips Oil AlasKa Oil & Gas Cons. Cem;nissio SohSo UnSon D & M NSK Ops. J. Rathmell Well Files ARCO Alaska, lnc.~..,. Post Office~ '360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 1/31/85 Transmittal No: 5014 RETURN TO: PAGE 2 of 3 ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ¢~ 1L-1 'CPL Cyberlook 10/08/84 Run 1 -- '" 2"/5" DI .-si L/O '10/08/84 " " 2"/5" Density Neutron"Poro" 10/08/84 2359 - 7470 2359 - 7447 " 2"/5" " " "Raw" 10/08/84 " 2359 - 7447 " 2"/5" BHCS/GR 10/08/84 " 6750 - 7473 2W-6 CPL Cyberlook 11/06/84 Run 1 3198 - 7286 2"/5" DIL-SFL/GR · "' 2"/5" Density Neutron "'Poro" 11/06/84 11/06/84 " 3198- 7286 - " '6600 - 7261 " 2"/5" " " "Raw" 11/06/84 " 5600 - 7261 i, .RFT "DIL-SFL/GR, FDC-CNL/GR" 11/07/84 2"/5" Density Neutron "Poro" " 2"/5" " i " 2"/5'' DzZ-S Z/o /cat Receipt Acknowledged: 10/31/84 Run 1 7350 -'-8050 10/31/84 " 3757 - 8080 " "Raw" 10/31/84 " 3557 - 8050 10/31/84 " 3757 - 8080 ... DISTRIBUTION B. Currier D~illing W. Pasher Chevron Mobil Phillips 0il ::.laska C~ .';, ('-.'as (;(;ns. C-ommisslor, State of 'AK!"'~/,~ Sohio Union D & H NSK Ops. J. Rathmell Well Files ARCO Alaska, Inc. Post Office~x 360 Anchorage,..,aska 99510 Telephone 907 277 5637 Date: 1/31/85 Transmittal No: 5014 RETURN TO: PAGE 3 of 3 ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. CPI~ Cyberl°_ok 2"/5" DIL-SFL/GR 2"/5" Densi'ty Neutron "Raw" 2"/5" " " "Poro" 10/01/84 ' Run 2 6050- 6520 10/01/84 " 3200- 6626 10/01/84 " 6050- 6600 10/01/84 " 6050 - 6600 2G-15 CPL CYberlook 2"/5" ~DC-C~/C~ "~or~" 2"/5" " "Raw" "2"/5" DILLSFL/GR Str~tigraphic Dipmeter SHDT ' -. 10/15/84 Run 1 6350 - 6894 '10/15/84 " 6350 - 6894 .. 10/15/84 " 6350 - 6894 - 10/15/84 " 2728 - 6934 : · · 10/'15/84 " 6350 - 6940 /cat Receipt Acknowledged: B. Currier BPAE Chevron D&M DISTRIBUTION .. Drilling W. Pasher Geology'~~ -' G. Phillips Mobil Phillips Oil NSK Ops. J. Rathmell ,Alaska 0~1 & Gas Cons. l¢ommission A~]chorage State of AK ~ · Sohio Union Well Files ARCO Alaska, Inc. is a subsidiary of AtlanllcRichfieldCompany ARCO Alaska, Inf---- Post Office...,Ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 1/23/85 Transmittal No: 4925 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 smitted herewith are the following items. Please acknowledge receipt return one signed copy of this transmittal. BHP REPORTS & SEQUENCE OF EVENTS 2B-l~ 10/16/84' '"Static" SBHP 2B-i~ .... 10/17/84 " " 2B-2}c-~' ~0/17/84 " " 2B-6X- _r_ 6/02/84 " 2B-10x~ 6/02/84 " 2B-11)C--6/03/84 " 2B-12N-- 6/02/84 " 2B-14~-~- 10/28/84 " " 2B-13y~ 10/28/84 " " 2D_5.A -- 10/05/84~ " ,,- 2G-l~ 9/21/84 "Static/G. Ring" 2G-2 * -' 9/22/84 " " 2G-3 .~ 9_/23/84 " " 2G-4 ~ 9/23'/84 " " 2G-8 +-- 9/30/84 2F-15, 4/13/84 2X-13~ 12/18/84 2X-14-~-' 12/21/84 2X-15.~.--12/23/84 2X-16~ 12/21/84 "Static/G. Ring/Tag~' SBHP Receipt Acknowledged: l~-3-g :~--' 6/26/84 -.. 1B-4x ..6/26/84 . lB-6 % -7/01/84 1E-2 w?' 6/22/84 1E-7 $ ~-~-'R/14/84 1E-4 ~-- 10/15/84 1E-12~.. 6/24/84 1E-20%~ 6/23,22/84 1E-22%~4/23/84 1E-25g-~ 6/23/84 1E-25~ 11/09/84 1E-29-$' 6/23/84 1E-29~ 10/14/84 1F-4 x 9/14/84 1F-4 ~ 9/14/84 17-7 ~ 7/05/84 1F-11 t~ 4/.25/84 1F-14~ .... 2/07/84 1F-15~- 2/14/84 lO-1, --' 6/29/84 ~iG-i~ ~ 9/13/84 /1~-3 ,.- 5/16/84 ,~ 1G-5 · 6/29/84 1}t-4 ~t-- 6/24/84 1Y-3 1~- 1/21/84 l¥-5 't'-' 5/06/84 1Y-9~.'- 5/06/84 1G-14.--' 1/12/84 1L-2z-- 10/21/84 iL-3 -~' ~ Date: DISTRIBUTION B. Currier Drilling W. Pasher BPAE Geology G. Phillips Chevron Mobil Phillips Oil D&M NSK Ops. J. Rathmell SBHP " "Static" " "Static" ,! '! ,, ,! ti It II II I1 " "Static" ,! ,, ,! ,, " ,, ,! ,, ,1 1, I, II " ,, /cat WeJll Files' ARCO Alaska, In' Post Office ='ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 December 6, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2B-13 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for the subject well. If you have any questions, please call me at 263-4944. Si ncerely, J. Gruber Associate Engineer JG/tw GRU2/L123 Enclosures RECEIVED Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany .,--..~-- STATE OF ALASKA ---. ~--. ALASK..~. .AND GAS CONSERVATION, , .tlSSION WI=LL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well 1. Status of Well OIL E~x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, inc. 84-104 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21138 4. Location of well at surface 9. Unit or Lease Name 1463' FSL, 597' FEL, Sec.19, T11N, R9E, UN LOCATIONSI Kuparuk River Unit At Top Producing Interval VFRIFIFD 10. Well Number 3825' FSL, 1280' FEL, Sec.19, T11N, R9E, UM Surf. ~i 2B-13 4082' FSL, 1350' FEL' Sec.19, TllN, R9E, UM · Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 125' RKBI ADL 25655 ALK 2581 ~ 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 115. Water-Depth, if offshore i16. No. of Completions 09/28/84 10/03/84 10/21/84I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 7145'MD,6350'TVD 7028'MD,6249'TVD YES I-X] NO [] 1899 feet MDI 1500' (Approx) 22. Type Electric or Other Logs Run D I L/SFL/GR/SP, Ca I/FDC/CNL, Gyro (GCT) 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" 224 sx Cold Set II 9-5/8" 36.0# J-55 Surf 2804' 12-1/4" 800 sx CS Ill & 250 sx CS II 7" 26.0# J-55 Surf 7110' 8-1/2" 320 sx Class G & 250 s~ CS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6792' - 6764' 3-1/2" 6672' 6650' & 6483' 6744' - 6730' w/4 spf 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 6630' - 6614' w/12 spf DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 6644' - 6646' 200 SX Class G 27. N/A 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 ~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Flow Tubing Casing Pressure CALCULATED Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED Alaska 0il & G'~s Cons, Commission Anchorage Form 10-407 GRU2/WC28 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ' '~ ~;~-/, ~-,-~, ,~ ............ . . - NAME ' - Include interval t~t~, pressure data, all fluids r~over~ and gravity, MEAS. DEPTH. TRUE VERT,; DEPTH ~ GOR;-and~tim~,.of.each phase. '- v . -~ .... L;. ';_;.-.:.:_.~.~ '. -::~ ; ....................... ' ...... . .. .. - Top Upper Sand 6613' ,~ : 5890' N/A "~S~ upPer Sand ~6632' :,. ;-' -5~6, ..... .- , . Top Lower Sand ~';::~0~' --. 5969~ ':;;~'.' '' - ..... ' ~se Lower sa~d' , 6862' ~ :'..; 6105' .... · , . ~ ~ - . ?-' :~--~;.~..y ~:.. - .. ..: . ._. ~- ~, :-~ , . ;:.-' ,~;.-;~.. :. .- . . . . . . . : : . ... ,~:.. t - . -~- ~ ,, . , . 31. LIST OF A~ACHMENTS : .: ; · -; ~ Well 'H~s~o~v~ Wo~kove~ ~ell Hi.s~o~v, CvrosCo.lc'.Su~vev (2-copies} ' 32. I hereby certify thatthe foregoing is true and co[r~t to the ~st of my knowledge Signed ~m~ ~ ,~'~W Title Associate Engineer Date INSTRUCTIONS General: This form is designed for:Submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which-elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and. in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interVal to be separately produced, showing the data pertinent to such interval. · Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ARCO iOir-and Gas Company Daily Well History-Final Report · InIlt~c~ Prepare and submit the "Final Report" on the'flint Wednesday after allowable has been assigned or well Is Plugged, Abandoned, or Sold. "Rnal RelN~t" should be submitted also when operations.ak"e:s~apended for an indefinite or appreciable length of time. On workovers when an official teat is not required upon. Completion, report completion and repre~-_te~t, data In blocks provided. The "Final Rel~rf' form may be used for reporting the entire operation if space is available. District: ICounty or Parish I Alaska Field ~Lease or Unit I Kuparuk River Auth. or W.O. no. ITitle I AFE 104973 Nabors 26-E Operator ]A.R.Co. ARCO Alaska, Inc. Spudded or W.O. begun ~Date I Spudded North Slope Borough ADL 25655 IAccountlng cost center code State Alaska IWell no. 2B-13 Drill Date and depth as of 8:00 a.m. 10/04/84 10/05/84 Complete record for each day reported API 50-029-21138 W.I. ITotal number of wells (active or inactive) on thisI Icost center prior to plugging and I 56,24% labandonment of this well IHour I Prior status If a W.O. 9/28/84 ! 1300 hrs I 9-5/8" @ 2804' 7145' TD, Prep to cmt 7" Wt. 10.1, PV 20, YP 6, PH 8.5, WL 5.2, Sol 14 RU & rn DIL/SFL/GR/SF f/7083'-2804', CAL/FDC/CNL f/7083'-6400' WLM, POH, RD Schl. TIH to 7095', rm to TD, C&C, POH. RU & rn 178 jts + 2 mkr jts, 7", 26#, J-55 BTC csg. RU to cmt. 7" @ 7110' 7028' PBTD, RR 10.1 filtered NaC1/NaBr Cmt 7" w/320 sx C1 "G" w/3% KC1, .7% D-19, .3% D-31 & .1% D-6. Displ w/10.1NaC1/NaBr, bump plug. CIP @ 0730 hrs, 10/04/84. ND stack, NU & tst tbg spool & lower tree assy to 3000 psi. RR @ 1530 hfs, 10/04/84. FC @ 7028', FS @ 7110', Mkr #1 @ 6594', Mkr #2 @ 6751' Arctic Pak w/250 sx CS I, followed by 58 bbls lightweight Arctic Pak. Old TO J New TD Released rigJ Date 0730 hrs Classifications (oil, gas, etc.) Oil Producing method Flowing Potential teat data PB Depth . IKi.d of rig 10/04/84 I Type completion (single, dual, etc.) Single J Official reservoir name(s) I Kuparuk Sands Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production ~Oil on test Gas per day :Pump size, SPM X length Choke size T.P. C.P. : Water % GOR Gravity Allowable Effective date corrected Signature 10/12/84 Drilling Superintendent AtlanticRichfieldCompany Daily Well History-Initial Report Instructions: Prepare and submit the !'InlUM, R_~..r~" on the .fim.t Wednesday after a well is spudded or workover operations are star, ed. Daily work prior to epud~Jt~mld I~® ~ummanzea on the form giving inclusive dates only. District I County or Parish Alaska I North Slope Borough Field ILease or Unit Kuparuk River I ADb 25655 1 Auth. or W.O. no. ~Titla AFE 104973 J Completion Roll'N #4 API 50-029-21138 Istata Alaska Operator A.R.Co'e W.I. ARCO Alaska, Inc. Spudded or W.O. begun IDato Hour Prior statua if a W.O. Completion I 10/16/84 1300 hfs IWell no. 2B-13 56.24% Date and depth as of 8:00 a.m. 10/17/84 10/18/84 10/19/84 The above is correct ~ ~.~j-~< ,.. Signature /-} F~r form preparatio~and distribution, see Procedures MaYual, Section 10, Drilling, Pages 86 and 87. Complete record for each day reported 7" @ 7110' 7028' ?BTD, 7145' TD, RIH w/3½" DP 10.1NaC1/NaBr Accept ri~ @ 1300 hrs, 10/16/84. ND tree, NU & tst BOPE to 3000 psi. RU SOS, perf 6644'-6646' @ 4 SPF w/4" gun. RIH w/CR @ set @ 6500', RD SOS. MU Bkr stinger on DP, RIH. 7" @ 7110' 7028' PBTD, 7145' TD, WOC 10.1NaC1/NaBr TIH, tag CR @ 6500', rev circ until cln. Sqz w/200 sx C1 "G" w/.4% D-22 & .4% D-6 w/final press @ 2600 psi. CIP @ 1700 hrs, 10/17/84. TIH w/BHA to 5415', WOC. 7" @ 7110' 7028' PBTD, 7145' TD, Prep to Chg Over to Cln Br 10.1NaC1/NaBr WOC. FTIH, tag cmt @ 6484'. RU & PU kelly hand tongs &std pipe, drl hard cmt. Drl to 6681'. Tst csg to 1500 psi, cln out to 7028'PBTD. Circ hole cln. LD kelly, chng bails, TOH, LD JB, MU BHA. PU T/S csg scr, TIH to 7028'. RU circ hd. RECEIVF_D DEC A~aska Oi~ & Gas Gens. Oonlmission Anchorage IDate 11/13/84 Drilling Superintendent AR3B--459-1-B Number all daily well history forms consecutively as they are prepared for each well. ' i Pag~ no. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "FiMI Re~' off the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Fna Report" should be submitted also whem'ol3eratione are suspended for an indefinite or appreciable length of time, On workovers when an official test is not required upon completion, report completloll a~d:representative test data in blocks provided. The "Final Report" form may be used tor reporting tho entire operation if space s available. '. Accounting cost center code District Alaska County or Parish Lease or Unit Tte North Slope Borough Stale Alaska Well no. ADL 25655 2B-13 Kuparuk River Aulh. or W.O. no. AFB 104973 Roll'N #4 Operator ARCO Alaska, Inc. Spudded or W.O. begun Completion Date and depth as of 8:00 a.m. Completion 10/20/84 thru 10/22/84 API 50-029-21138 IA.R.Co. W.I. il'eta' number of wells (active °r inactive' °n thisI lcost center prior to plugging and 56.24% [abandonment of this well I Date IHour I Prior status if a W.O, lO/16/84 | ~3oo hfs [ Complete record for each day reported 7" @ 7110' 7028' PBTD, 7145' TD, RR Crude/Diesel Chg over to cln brine, POOH, LD DP. RU SOS, PU 4" gun 4 SPF, perf 6792'-6764', no misfires. Perf Rn #2, perf f/6744'-6730'. Rn #3 w/5" gun, perf 6630'-6614' w/12 SPF. RU 6.125" gage ring/JB to 6950'. PU & MU W/L pkr assy, set same @ 6650'. Rn 148 jts, 3½", 9.3#, J-55 IPC 8RD EUE tbg. MU Otis FMX SSSV, RIH w/total of 207 jts, 3~" tbg. Lnd tbg, press tst seal assy to 300 psi. Set Camco HRP-1SP ret pkr, shear OEJ w/100K, MU Gray modified tbg hgr & re-lnd tbg. Displ well w/30 bbls diesel, followed by crude. Fin displ'g well w/230 bbls crude. SITP = 275 psi, SICP = 650 psi. Tst SSSV f/15 min; OK. Tst orifice; OK. Press tbg to 4200 psi & shear out. Bleed press to 1000 psi over SITP = 750 psi. Shut well in. Set BPV & secure well. RR @ 1330 hrs, 10/21/84. Otis FMX non-equalizing SSSV @ 1899.36' Camco 7" HRP-1-SP Hyd Pkr @ 6482.74' Bkr FB-1WL pkr set @ 6650' Btm of tbg tail @ 6671.66' Old TD Ne.w TD PB Depth 7145' 7028' PBTD Released rig Date Kind of r g 1330 hrs 10/21/84 Rotary Classifications {oil, gas, etc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no_ Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above i ....... t f ,-~'/~ Signature _~)~~ For form preparation and d~stribution, see Procedures Manual, Section 10. Drilling. Pages 86 and 87. Drilling Superintendent AR3B-459-3-C Anchor~e, Number all daily well history terms consecutively I Page ~o. es they are prepared for each well. Dlvllto~l of Afl~t~M~ld~Y : Kuparuk RiVer, Au~, or W,~ ~. ' ' ~ 104973:~:~:: ilY::Well H ry-,nitlaF :!-:: or Pariah North Slo )e Borough L~ or Unit ADL 25655 JState Alaska Veli no. 2B-13 Tltle Drill Nabors: API 50-029-21138 Operator ARCO Alaska'~ Inc. Spudded 9/28/84 1300 hfs Date and depth Complete record for each day reported al of 8:00 ~.m. 9/28/84 9/29/84 thru 10/1/84 10/2/84 lO/O3/84 16" @ 110' RU. IA~R. Co's W.L 56.24% Prior statu~ if a W.O. 9-5/8" @ 2804' 2935', (2832'), Drlg Wt. 9.0, PV 6, YP 8, PH 10, WL 19, Sol 5 Accept ri~ @ 0700 hrs, 9/28/84. NU diverter sys. Spud well @ 1300 hfs, 9/28/84. Drl & surv 12~' hole to 2825', short trip to 1425', CBU, POOH. RU & rn 70 its, 9-5/8", 36#, J-55 HF-ERW BTC csg w/FC @ 2722', FS @ 2804'. M&P 800 sx CS III @ 12.2 ppg, followed by 250 sx CS 'II. Displ using rig pmps, bump plug. CIP @ 0650 hrs, 9/30/84. ND diverter sys. Perform top Job w/29'sx CS II. NU &tst BOPE; OK. PU BHA, RIH to 2720', tst csg to 1500 psi. DO FC @ 2722', cmt, FS + 10' new formation. Conduct formation leak-off tst to 12.5 EMW. Drl & surv 8½" hole to 2935'. 1766', 4.7°, N10.5E, 1765.87 TVD, 4.32 VS, 4.68N, .87E 2081', 12.4°, N2.SW, 2076.61TVD, 50.98 VS, 54.15N, 6.30E 2525', 26.5°, Nll.5W, 2494.06 TVD, 198.25 VS, 199.27N, 20.48W 2742', 32.4°, N19.5W, 2683.61TVD, 303.53 VS, 300.35N, 50.19W 2884', 33.6°, N13.5W, 2802.70 TVD, 380.76 VS, 374.47N, 72.14W 9-5/8" @ 2804' 6412', (3477'), Drlg Wt. 10.1, PV 15, YP 10, PH 9.0, WL 8.2, Sol 10 Drl & surv 8½" hole to 6412'. 3100', 34.5°, N15.5W, 2981.66 TVD, 501.69 VS, 491.56N, 102.42W 3606', 35.3°, N17.SW, 3396.03 TVD, 791.72 VS, 769.35N, 187.03W 4238', 35.9°, N16.5W, 3909.58 TVD, 1159.70 VS, 1122.06N, 293.18W 4860', 35.3°, N18.5W, 4414.52 TVD, 1522.42 VS, 1467.81N, 405.50W 5487', 33.2°, N15.5W, 4933.22 TVD, 1874.24 VS, 1805.02N, 507.08W 6302', 31.4°, N16.5W, 5617.97 TVD, 2315.95 VS, 2229.26N, 631.17W 9-5/8" @ 2804' 7145', (733'), Prep to rn OHL Wt. 10.1, PV 15, YP 8, PH 9.0, WL 5.8, Sol 12 Drl & surv to 7145', CBU, 15 std short trip, C&C, TOH f/logs. 6500', 30.3°, N13.5W, 5787.89 TVD, 2417.48 VS, 2327.33N, 657.45W 7085', 31°, N12W, 6291.17 TVD, 2715.61VS, 2618.21N, 723.27W 7145', 31°, N12W, 6342.60 TVD, 2746.49 VS, 2648.43N, 729.70W JDate J Title The a~ov~' Signature RECEIVED Alaska Oil & Gas Cons. Commission At,,.t ....... ADDENDUM WELL: 10/04/84 10/08/84 2B-13 Arctic Pak w/250 sx CS I, followed by 58 bbls Arctic Pak. Rn CBL/VDL/GR f/7020'-5000' WLM. Rn GCT gyro f/6974'-surf. RECEIVED F E B 2 5 1985 Almska Oil & Gas Cons. ¢omm]~ioll Anchorage -~rillin~ S~perintendent D'a~e $ UB-$ URFA CE DIRECTIONAL SURVEY F'~ UIDANCE ~IoNTINUOUS r-~ OOL Company ATLANTIC RICHFIELD COMPANY Well Name Field/Location 2B-13 (1463' FSL, 597'FEL, S19~ T11N, R9E, UM) KUPARUK, NORTH SLOPE, ALASKA Job Reference No. 69618 Logged By: PEPPEL Date 0CT-18-84 Computed By: STEVENS * $CHLUNBERGgR * GCT DIRECTIONAL SURVEY FOR ARCO ALASKA, INC,: 2B-13 KUPARUK NORTH SbOPgw ALASKA SURVEY DATEI ENG'INEERi PEPPEb METHOD& OF COMPUTATION TOOL LOCATIONI TANGENTIAL- averaged deviation and az&muth INTERPOLATIONI LINEAR VERTICAL SECTIONI HORIZ, DIST, PROUECTED ONTO A TARGET AZIMUTH OF NORTH 14 OEG ll NIN NE&T COMPUTATION DATEI 17-0CT-84 PAGE 1 ARCO AlaASKAp XNC. 2B-13 KUPARUK NORTH SLOPE~ AbASKA DATE OK'$URVE¥1 7-0CT-84 125.00 F~ INTERPOlaATED VAbUES FOR EVEN 100 FEET OF NEASURED DEPTH TRUE SUB,,6~I COURSE MEASURED VERTICAL VER?! la DEVZATION AZIMUTH DEPTH DEPTH DEPTH DEG .IN DEG VERTICA~ DOGLEG R£CTANGULAR COORDINATES HORIZo DEPARTURE SECT!ON SEVERITY NORTH/SOUTH EAST/NEST DZST~"' AZZNUTH FEET DEG/IO0 FEET FEET FEET DEG NXN 0 O0 00 O0 O0 O0 O0 O0 4O0 O0 500 O0 600 O0 7O0 O0 800 00 9O0 O0 0 O0 -125 O0 100 2OO 3OO 4OO 5O0 6O0 7OO 8OO 9OO O0 -25 O0 75 O0 175 oo O0 O0 75 00 00 675 O0 775 0 0 N 0 0 E O0 0 7 N 78 32 W 00 0 15 N 67 46 W 00 0 '16 $ 82 47 W O0 0 7 $ 70 2 W O0 0 14~ N 78 45 . 00: 0 9. $ 44 31W O0 0 7 N 32 OW 00 0 9 N 84 3 W O0 0 11 N 29 2 E 0.00 0.05 0.21 0.41 0.36 0.49 0.49 0067 .78 0 O0 0 0 0 0 0 0 O0 N 98 0 13 0 28 0 26 0 21 0 27 0.00 04 N 0.04 12 N 0,37 21 N 0,84 07 N 1,16 14 N 1,44 04 82 O0 N 0 0 E 06N 42 9 W 75 48 iSN 86 25 w N94 19 W 90 , 22 1000 O0 1100 1200 300 ~400 ,o§ 1700 1800 1900 O0 1099 O0 1199 O0 1299 O0 1399 O0 1499 O0 1599 O0 1~9999 99g 99 99 974 98 11 97 27~ 96 ~3 93 1 98 I 874 99 0 7 90 0 45 98 0 39 98 0 o 96 0 93 155 69 5 27 98 8 27 N 48 25 E $46 21E $ 39 '53 E $ 29 1 E 8 3923 E $ 2228 E S 2545 E N 27 28 E N 10 45 E N 7 15E , 09 0,74 0.59 .,, o.,, o.,, 004 5,31 5, * 2000 O0 1997 oo oo O0 2 2400 2500 O0 28OO ~900 O0 2381 47 0000 1562 O0 2649 O0 2734 O0 2817 54 1872 38 1970 38 2067 80 2162 36 256 72 134'7 O0 2437 54 2524 03 2609 142692 54 ii 2~ N 8 29 E 38 13 4i N 2'29 W 38 15 N 8 36 W 80 19 N 11 31 w 3 N 10 30 ~ 54 N 3 W 03 33 50 N 18 53 ~ 14 34 6 N 15 57 W 26 45 69 99 134 2O 68 86 62 89 43 44 61 78 33 2 4 1 240 289 i ti 4 3O 40l ! 96 0 86 29 58 N 3 N 38 59 N 56 ,81 N 72 $1 03 ~ 2~0 63 w 322 71 W 377 oo I 3 N 5 0 N .8 0 N 3200 56 2939 3300 30 3400 31~ 3500 3900 2 82 O0 28 O0 10 3392 oogg O0 3636 72 63 39 3185 3430 68 3511 68 34 24 15 34 7 72 5 63 35 86 35 34 35 68 35 N 16 6 W N 16 16 N 1 6 24 W N 16 31 N N 16 4°~ 7 0 N 17.20 N 17 25 N 433 76 546 603 84 66!76916 891 70 949 79 0 63 0 23 0 28 011 0 2O 104, 4900 588e42 ~ ,,,. 864037 219. 891, 236, 949, 'ARCO ALASKA, INC. 2B-13 KUPARUK NORTH SLOPE, ALASKA COMPUTATION DATEI 17-0CT-84 PAGE 2 DATE OF SURVEY1 ?-0CT-84 KELLY BUSHING'ELEVATIONI 125,00 ET ENGZNEERI'PEePEb INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG 4000,00 3718,05 3593 !I00.00 3799.26 3674 00.00 3880.41 3755 O0 O0 396{.52 383~ !!oooo O0 O0 4t23.63 O0 O0 4204,77 4079 4700 O0 4286,01 416! 4800 O0 4367.52 4242 4900 O0 4449;35 4324 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ,. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/NEST DIST,':' . AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MXN 1066, . . 35353145 ~ 18 18 ~ ~]57,1295 §,22 ~309,30 416 , . · .25 1364.'72 5 ,35 34 17 56 531, ~,60 1474,46 50005 0 O0 453137 4406,~70 34 4~ 51002 0 O0 4613 70 4488. 34 2 O0 4696 42 33 55 4571042 5300 O0 477964 4654.64 3 7 5400 O0 4863 21 4738.21 31 211 5600 O0 5030 8 4905,88 3 3 ~700 O0 511457 4989.57 33 ~46 800 O0~ 51980'55073.05 33 5900 O0 5281 53 5156,53 33 19 O0536 O0 544~ O0 5534 O0 5619 O05705 O0 '5791 O0 5878 O0 5965 O0 6051 O0 6138 38 5240 6.3 5324 27 409 38 ~494 O6 5580 42 5666 22 5753 18 5840 82 5926 17 6013 6224.56 310,95 349,82 ~ 3239 ~7 31 38 31 42 30 4 0 82 3015 1,7 3014 6099.56 30 14 6185,95 30 14 6224,82 30 14 6OO 6300 6400 6500 6800 6900 7000 O0 7100~00 7145,00 N 17 54 W 1588 36 N 17 37 W 1645 N 17 8 W 1701 N 16 25 N 1756 N 16 19 W 1811 N 16 9 W 1865 N16I!WW 1920 N 16 1975 N 16. W 2030 N 16 W 2085 O0 10 50 37 ,04 ,06 O5 N . N 1653 W 2246 N 17 5 W 2298 N 16 38 W 2350 N 16 27 N 2400 N 15 5 499 N 1538 N 2549 N 1514 W 2600 49 31 44 '/8 N 14 53 W 2650,49 N 1453 W ,53' 0 65 036 0 58 0 57 041. 052 0 0 41 0 63 0 89 0 0 0 0 0 0 0 ,0 1528,87 43 99 ,01 48 45~' : 1589 1582092 ~ ~ [ 52 1794076 ~ 49 0 513. ~ 1812 1899,55 ~544,4'30 ~ 19~t.03 1952'37 ~ 2005014 ~ 559.96 20~1.08 2086,~1 1¢ O, 2 i 36 2~59 64 ~2307 45 2450 46 2499 36 N 591 94 N 606 N, 86 N 694 94 N 708 53 N 721 2548,~08 N 2596, N 2618,79 N 0.00 0,00 00.00 15 W 2140 68 W 2194 ,2300 03 W 2551 45 N2601 734 47 W 2!,9 N . 65 4 16 4 W W 27020'30 N 16 W COMPUTAT/ON DATEI 17-0CT-84 PAGE ARCO AbASKAw ZNC. DATE OF SURVEY{ 7uOCT-84 2B-13 KEb~Y BUSHI'NG EbEVATION~ KUPARUK NORTH SLOPE~ AhASKA ENGINEERI XNTERPObATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPT TRUE SUB-SEA COURSE VER?ICAb DOGGEG RECTANGUbAR COORDXNATES HORIZe- DEeARTURE MEASURED V£RTICAb VERTICAb DEVIATION AZIMUTH SEC?ION SEVERITY NORTH/SOUTH EAST/WEST D~8~i.. A~NUTH DEPTH DEPTH DEPTH DEG MIN DEG ~IN FEET DEG/IO0 FEET FEET ' FEET D~G NIN .. o.ooo.oo-,~.oo ~ ~ ~ .~ ~g [~.oo oo oo · ,74 ,59 , , ,ooo.oo ,~.~,,,.~, !ii~' ~ ~ ~ ~ ii! 3000 O0 2899.68 2??4.68 16 . , . . N 589 20 734 265 49 O0 , , 65~ N.16 4 . . 14 53 . . 2548 ,94 N 7145,00 6349.82 6224,82 14 N 14 53 W 2723,53 0.00 2618,79 N 753, W 2724,97 16 2 125.00 FT COMPUTATION DATEI 17-0CT-84 ARCO ALASKA, INC. 2B'13 KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEYI 7-0CT-84 KELLY BUSHING ELEVATION{ 125.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE NEASURED VERTICAL VERTICAL DEVIATION AZIHUTH DEPTH DEPTH DEPTH DEG MIN DEG VERTICAL DOGLEG SECTION SEVERITY FEET DEG/IO0 RECTANGULAR COORDINATES HORZZ, DEPARTURE NORTH/SOUTH EAST/WEST DIST, · AZIMUTH FEET FEET FEET DEG MXN 0 O0 25 O0 125 O0 oo 2 O0 425 O0 525 O0 625 O0 oo O0 125 225 325 425 525 625 725 825 O0 -125.00 ,00 -100.00 O0 0.00 O0 lO0 O0 O0 200 oo O0 400 O0 O0 500 O0 00 6O0 00 00 700 O0 0 0 N 0 0 E 0 5 N 5 32 E 0 9 N 84 44 N 0 16 N 70 27 W 0 14 S 7211 W 0 7 N 82 40 W 0 15 S 88 54 tv 0 6 S 36 22 tv 0 10 N 52 51 W 0 5 N 85 6~ ,00 0,00 0,00 0,00 E 0,00 ,27'00 0,080'00 0.00 ~~ o. oo.o §:oo o.o. .,o o.,, o.oo ,.,,, ,.., 54 0,27 07 ,69 0,32 14 ~ ,24 ~ 2,25 925 O0 9 .00 1~25.00 1 25 O0 800.00 900,00 1000.00 025 1325 18 02 1100.00 03 1325 O0 1200.00 03 1425 O0 1300,00 04 1525 O0 1400,00 °° oo O0 1600,00 1825 O0 1700.00 0 14 N 20 29 E 0 13 S 65 41 E 0 47 S 45 48 E 0 35 S 33 5 E 0 39 S 33 24 E 0 41 S 32 19 E 0 52 S 22 56 E 0 52 $ 26 57 E 3 6 N 18 45 E 6 13 N 9 57 E 0.85 1,07 -2.95 -4.34 -5,91 0 17 098 008 o 0 0 $0 0 2 0 33 N 0 59 N 1 1978 2 84 S 4 13 S 5 57 S 4 49 S 351 N ~,19 tv ,06 tv 1,26 tv 0,41 W 0 E ,0 ~ 221 N 813i W 214 N 74 5 N 137 $ 84 51 W I $ 2 E 295 615 ~E S 18 E 36 54 E 2339 2671 2789 2909 34 1925 03 2025 · 40 2125 .95 2225 50 2325 ~3 2625 13 2725 49 2825 0 2000 0 2S00 O0 2200 24O 25OO O0 2600 O0 2700 O0 9 7 N 815 E O01142 N 87 E O0 1325 N7 19 tv O0 1644 N 930 W 00 20 19 N 12 37 W O0 2359 N 10 59 W O0 27 7 N13 0 ~ O0 29 2! N 19 21 W O0 33 39 N 19 14 W O0 34 11 N 15 57 tv 254 65 1 0 3 4 I' 2 0 82 :53 55 85 56 83 116 N 9 69 N 9 20 N 5 26 N 0 94 N 9 N .33 88 N 54 93 N 74 98 E 5~ 87 E 83 69 W 116 5 ~ 03 58 tv 56 9_7 N 22 .~ E ~v N' t5 E: 56 N 9~ E 41, N 4 '2 E 26 N 0 20 W N 326w N 513W 63 N 9 56 tt ~8 N ~ 9W 3030 70 2925 4OO 4131 97 3025 8615 342~ 74 3525 25 64 00 2800,00 34 27 00 2900,00 34 28 00 3000.00 34 46 00 3100.00 35 4 O0 3200,00 35 10 O0 3300,00 35 1! O0 3400,00 35 26 ggIi°°'°° . 00.00 35 O0 3 00.00 35 44 N 16 10 W N 16 28 W N 1634 W 658 N 16 32 W 728 N 16 47 tv 799 N17 24 N 941 N 1724 W 1012 N 17 3O W 1084 45i.10 68 74 8O $5 0 16 0 32 046 027 02 o ½~ 0 ~ 044 441,76 9310 ~ 451,46 ~ I~ 54 507,63 ~ 12 32 59,9i 28 ~ , , ~ 56 640 ~ 5186 708. "'. i 911, . 33,94 1048,64 77.02 COMPUTATION DATE! 17-0CT-84 PAGE 5 ARCO ALASKA, INC. 28-13 KUPARUK NORTH SLOPE; A~ASKA DATE OF SURVEY1 ?-0CT-84 KELLY BUSHZNG EbEVATIONI 125.00 FT VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE &UB-SEA COURSE MEASURED VERTZCAL VERTICAL DEVZA?/ON AZINUTH DEPTH DEPTH DEPTH DEG NZN DEG MZN VERTICAL DOGLEG RECTANGULAR COORDINATE8 "ORXZ, DEPARTURE FEET PEG/1 oo FEET FEET FEET D~G 4378 25 4025 O0 .00 ~5 49 ~ . §.27 11!7.34 N 4 N 4624 93 4225 O0 4!00 O0 5 43 18 1372,48 36 4747,87 4325 00 4200.00 22 ~ 18 1443.83 5~13 69 4625,00 4500 O0 34 .~2 ~7 32 ~ ~S83 5234.4~ 4725,00 4600.00 ~3 46 ~654, ~ 47 °7O ~ ~72~,05 . . ,~ ~ ~ ,~o.~, g ,~ 1.786. 49~,56 1787.21 N 5473 79 4925 O0 4800 O0 5591 57! 6O7 6589 6538 33 4 99 5025 48 5S25, 29 94 ~225 325 79 5425 52 09 562~ 59 5 t6 5725 78 5825 O0 4900 O0 5000 00 5300 00 5400 O0 550O 00 5600 O0 5700 O0 3 2 O0 3~ 7 oo i~ ~ O0 3 0 00 OD t~ ~ O0 31 24 00 30 27 O0 29 49 6 5 7000 5925 6025 6 49 ~ ~oo.o~ 5900.0 0 5 000066000'0§ ~ ~45 oo ~½~:~o ~o 82 6224082 30 N 16 9 N 1851,69 N 16 12 W 1916.52 N 16 32 W 2047 N 16 34 W 2! N 1649 W 2 77.46 N 17 8 W 2302 N 16 40 W 236 N 16 22 W 2420 19 N 15 W ,90 55 2476 N 15 ~I W 25~1.43.12 N 15 W 25~ N 14 53 W 2650.74 N 14 53 w 2709.05 N 14 53 W 2723.53 0 85 0 30 0 59 o~ 0 0 48 o g~ 0 0 85 0 74 0 78 0 39 0 O0 0 00 0 00 1843.33 , 528 02 1917.47 59 546 36 !982.86 1906.10:~ 655 2363,55 2270.70 ~ 2303, 2326,34 672.44 2421.58 16 2380 85 688 19 2478 32 2435 92 ~ !I 2535 56 ~o~ ~ ARCO AbASKAr ZNC. 2B-$3 KUPARUK NORTH SbOPE~ ALASKA MARKER TOP UPPER SAND BASE UPP£R SAND TOP bOWER &AND BASE LOWER SAND PBTD TOTAL DEPTH COMPUTATZON DATEI 17-0CT-84 PAGE 6 DATE OF SURVEY1 7-0CT-84 KELLY BUSHZNG EbEVATZONI 125.00 rT ENGZNEERI PEPPEL INTERPOLATED VALUES FOR CHOSEN MEASURED DEPTH BELOW KB 66t3.00 6632.00 6704.00 6862.00 7028.00 7145.00 ORIGIN= 1463' FSL~ 597' TVD FROM KB SUB-SEA 5889,53 5764,53 5906.07 578~.07 5968.65 5843.65 6105,36 5980.36 6248,75 6123,75 6349,82 6224,82 SURFACE LOCATZON A? FEb. SEC 19. TI1N RgE~ UM RECTANGULAR COORDinATES NORTH/SOUTH 361.55 N 68~. 2404.76 N ARCO ALASKA~ INC, 2B'13 KUPARUK NORTH SLOPE~ ALASKA 'MARKER TOP UPPER &AND BASE UPPER 8AND TOP LONER 6AND BASE.LONER SAND PBTD TOTAL DEPTH COMPUTATION DATEI 17-0CT-84 #EASURED DEPTH BELOW KB 6613 O0 6632 O0 6704 O0 6862 O0 7028 O0 7145 O0 DATE Of SURVEY1 7-0CT-84 KELLY BUSHING EbEVATIONI ,. ENGINEERI PEPPEb PAGE 7 125.00 FT SURFACE L, OCATION AT ORIGINm 1463~' FSi,, 597' FEI....SEC 19~ TI1N. RgE~ UM TVD RECTANGULAR COORDZRATE$ i~'RO~ KB 8UeLSEA NORtH/SOUTH EAa~/~E~ 5889,53 5906,07 5968,65 6105,36 6248,75 6349.82 5764.53 5781 07 5843 65 598O 36 6123 75 6224 82 70 2404 2481 2561 2618 55 N 682,69 4 N 6'85,.~97 6 N 695006 FINAL NELL LOCATION AT TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 7145,00 6349,82 6224,82 HORIZONTAL DEPARTURE DI$TANCE AZIMUTH FEET DEG NIN 2724.97 N 16 2 W SCHLUMBEROER ARCO ALASKA, INC. KUPARUK NORTH SLOPE, ALASKA OCTOBER 7, 1984 TVN PLOT FROM OCT DATA JOB REFERENCE . 69618 WELL' 2B-13 SURFACE LOCATION' 1463' FSL, 597' FEL, S19, T11N, R9E, UM VERTICAL PROJECTION - 1000 -~00 0 0 ~ 1000 1 ~00 2000 ~SO0 PROdECTION ON VERTICAL PLANE OF AZIMUTH ~4~ 84;PI. E0 IN VEI~TICAL DEPTH5 HORIZ SCALE = I/S00 IN/FT 'WELL: 2B-13 'SURFACE LOCATION: 1463' FSL, 597' FEL, S19, T11N, R9E, UM HORIZONTAL PROJECTION ~000 1000 SOO REF 6961EI SCI:I.£ = l/~ N/FT ::.Z.'.'.'.:.T..~:~i~:'~:.T2T_:Z-.~"'F~'":'":"""~"'~"4"';" .-~-.+.-+....+.~..~-..: ........ :::::::::::::::::::::::::: --¢..~.-.~-.f.~?.S,,~,~c;-..!..-...'-'-.Tk,..?.!..~-...-~.~-:..-...~ .............. ~.. ::::::::::::::::::::::::::::: ..... · ..;...~...,...~...i ~ ........ ~. : i ! : ' ';'; i ' ' ' , !' ! 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L'-------:..:.; ........... : I.: ........ :'"i ....... : ...... I-..: ........ :~::-.1 -- ' ' ! ' ' ........ I ..... I ' I J " · -:...:.-.i--.i--.i-..4...~--4-.4...l-..;...f..-~.-~..-~-..i-.-;.-.i.-.i ........ ! ~..4-..i..-f..!-4-.~-.-...ti..-u...i...i..4-..X.-!x-..- ....... :..-"..:.-.6-.:-.: ............... t :..:..L--..- .: ........... t ,. :...: ...... I..: ..... : T.-7:.".-.-.~ "T":'"T"-."'i'":."':."':"f'" '":"'?'~'-'?"*,.'":'":.."'? ...... :'-f'i"--.."-f--..-'---.:"-~-.---- --f--~---f~--i-.+-~-.-:--4-- --.:..;---:.-:--T--:.--:-.-:---: ...... :'":':' :' f" :"': ':'": ..... :': ...... :' r' :' :":: :'":': ': ~ : : : : '~ -3000 -2SO0 -201:)0 - ] SOO - ] 000 -SOO 0 SOO EAST Sug 'form to be inserted in each "Active" well folder to d~.eck for timely compliance with our regulations. ' '' Operatdr', ~ell'N'ame and Number Reports and Materials to be received by: j/ '-~0-~ Date Required Date Received · · Completion Re~ort Yes · Well History Yes L · -.. Son. les ~ , .. ~r e ~ips -' '~.'4~' ~ -- _Core ~scrip~on ~ ,~~. .,Registered S~ey Plat ~S ?~//' ~ Inclina~on S~ey /V~ ~ Dire~ional ~ey y~,~~/ ,/~ ~/~_~~~ Drill St~ Test Re~s ~/~~- ~S R~ .' ~) Yes - ~ ._ ~... ~ ....... ..~'_ ~,.~ . ARCO Alaska, I.r~. Post Offi~:~'~'--- 360 Anchorage, P.-,ska 99510 Telephone 907 277 5637 Date: 11/27/84 T~ansmittal No: 4868 RETURN TO: ARCO ALASKA, INC. = ATTN: Records Clerk ATO-1115B P.0. Box 100360 T~~ransAnChorage, AK 99510 mitred herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. CBL' s/Schlumberger/FINALS "Variable Density" "GCT/JB/GA" 9/19/84 Run 1 " " " 9/31/84 " " " "GCT" 10/07/84 " " " "GCT" 10/07/84 " " " "GCT/JB/GA" 9/31/84 " " " "GCT/JB/Ring 9/17/84 " " " "GA/JB/GCT" 9/19/84 " " " " 9/17/84 " " "GCT" 7/21/84~ " " " "GCT" 9/21/84 " " " "GCT/GA/JB" 9/14/84 " " " " ~/15/84 " " " -"OCT/JC" 10/12/84 " " " " 10/15/84 " " .-" " 10/12/84 " " " " 1o/13/84 " " " "GCT/~VB/GA'' 10/22/84 " " " " 10/22/84 " " " "JB / GA" 8 / 19 / 84 " " " " 8/20/84 aun 3 " " 9 / 21/84 Run l " " "GCT/JB" 10/14/84 Run 1 " " " lO/14/84. " " " " lO/O5/84 " " " "GCT" 10/05/84 " " " "Perf 4"= 9/10/84 Run 2 5 1/2"/PPS/JB" Acoustic "VDL/Signature/GR" 11/05/84 Run 1 /cat Receipt Acknowledged: B. Currier BPAE ~ 6597 - 8292 ~-'2B-3 7000 - 8460 -/2B-16 '/ 4950 - 7004 5750 - 8408 .~2B-14 5700 - 7970 *~2B-!5 5348 - 6824 ~2B-2 7250 - 9182 -~B-4 5055 - 6487 ~B-i~ 6200 - 7866 ~2D-5 6800 - 8954 --~2D-6 5054 - 6650 5597 - 8084 -- 5650 - 7951 ~2G-9 58~0 - 8524 --2G-11~ 4940 - 6765 -2G-10~~ 5730 - 7950 -2G-12 5790 - 7814 - 2G-13 5989 - 8624 8650 - 9334 .-~F-6 ~' 8650 - 9562 1F-6 5692 - 6742 ~lY-5/. 7ooo- S~o DISTRIBUTION · Drilling W. Pasher Geology'-/~Z.~ G. Phillips 6100 - 6992 ~*1E-24 Sohio Chevron Mobil Phillips Oil Union D & M NSK Ops. J. Rathmell Well Files' ARCO Alaska, Inc. Post Office x 360 Anchorage,' ~-~l'aska 99510 Telephone 907 277 5637 Date: 11/07/84 Transmittal No: 4~38 RETURN TO: .. ARCO ALASKA, INC-. - ATTN:. Records Clerk ~0. Box 100360 /Anch°rage, AK 99510 ' _ Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH LIS TAPES/Schlumberger /7/69612 1L-1 10/08/84 Run 1 /#69613 1L-2 10/01/84 Run 2 ~#69591 2B-13 10/03/84 Run 1 /#69596 2G-12 9/23/84 " / #69594 2G-14 10/08/84 " /#69595 2D-3 10/08/84 " f #69623 2D-2 10/16/84 " 2317 - 7486.5 ,.,Z_~:~, 3188 - 6643.5 -~-'~"?'~"~ ~-~' - 2795 - 7105.5 ~ - 2883 - 8148 ~ /cat Receipt Acknowledged: B. Currier Drilling BPAE Geology Chevron Mobil D & M NSK Ops. Date: DISTRIBUTION W. Pasher G. Phillips Phillips Oil J. Rathmell State of AK Sohio Union Well Files .. ARCO Alaska, Inc.~-_- Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 23, 1984 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Monthly Reports Dear Mr. Chatterton: Enclosed are the Monthly State Reports for the following wells' 2G-9 1L-8 2D-6 2B-16 2G-10 1L-4 2D-5 2B-15 2G-11 1L-3 2D-4 2B-14 2G-12 1L-2 2B-13 2G-13 Sincerely, Area Dril ling Engineer JBK/SH/tw. HILL/01 Enclosures RECEIVED NOV 0 5 l~J, Alas:-..~ O~J & Gas Cons. Commisslorl Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanlicRichfieldCompany STATE OF ALASKA ALASKA Ch~'AN D GAS CONSERVATION COM~IISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS '1. Drilling wellY[~ Workover operation [] 2. Name of operator ARCO Alaska, I nc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well atsurface 1463' FSL, 597' FEL, Sec.19, T11N, R9E, UN 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 125' RKB, Pad 89.5' ADL 25655 ALK 2581 7. Permit No. 84-1 04 8. APl Number 50-- 029-21138 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2B-13 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of. September · 19 84 2. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 1300 hrs, 9/28/84. Drld 12-1/4" hole to 2825'. Ran, csg. Performed top job w/29 sxs CS II. Drld 8-1/2" hole to 7145'TD logs. Ran, cmtd & tstd 7" csg. Secured well and released rig Permformed Arctic pack. cmtd & tstd 9-5/8" as of 10/3/84. Ran 1530 hrs, 10/4/84. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 9-5/8", 36#, J-55, HF-ERW BTC csg w/shoe @ 2804'. Cmtd w/800 sxs CS 7" 26# J-55 BTC csg w/shoe ~ 7110' Cmtd w/320 sxs Class "G" III & 250 sxs CS II. 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/SFL/GR/SP f/7083' - 2804' Cal/FDC/CNL f/7083' - 6400' 6. DST data, perforating data, shows of H2S, miscellaneous data N/A RECEIVED NOV o 5 Alaska 0ii & Gas Cons, Commission An~h0mge 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED TITLE Area Drilling Fngineer DATE _ NOTE--Rep~/r(on th~/~o~/c~/is required for each calendar month, regardless of the status of operations, and must be (iled~ir p' te with the Alaska Oil and Ga~onserva/o/~ommission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 ~" H I LL/MR06 Submit in duplicate M EMORA"NDU M TO: TtlRU: FROM: Staz'e' of Alaska'. ALASKA OIL AND GAS CONSERVATION COI~ISSION C. V. ~rton Chairn~a~. ~_~~'' Lonnie C. Smith Co~nissioQer Edgar W. Sipple, Petroleum In~peeto~~' DATE: October 5, 1984 FILE NO: D. 51.73 TELEPHONE NO: SUBJECT: Witness BOPE Test on ARCO' s Kuparuk 2B-13, Sec. 19, TI IN, R9E, Permit No. 84-104, Nabors Rig 26E. Saturday._, _September 29, 1.98_4: I traveled this date from Anchorage via Alaska Airlines to Prudhoe Bay, ARCO's Kuparuk 2B-i3, Nabors Rig 26E, to witness a BOPE test. The drilling contractor was in the process of running casing. Sunday~ September 30, 1984: The BOPE test commenced at 3:45 pm and was concluded at 6:15 pm. There was one failure. The annular preventer leaked; worked it several times, flushed the system. Then 1,800 pounds of pressure was held on annular preventer for 10 minutes. I filled out the AOGCC BOPE inspection report which is attached to this report. In summary, I witnessed the BOPE test on ARCO's Kuparuk 2B-13, Nabors Rig 26E. Attachment 02-00 lA(Rev. ~0179) Operator' Well Location: Sec / ? TJ.L~_~ ~6L.M Drilli~E Contractor G/~~$ Location, General~ ~.~ Well Sign_~_~ General Housekeeping~__~_~_Rig. Reserve Pit Mud Systems Visual Audio .,L Representative / Ri~ f~'~ ~ -.Representative ~, ~/~_~ - ' ACC~ATOR SYST~ Full Charge Pressure ~~' psig Pressure After Closure /~ psig Pump incro clos. pres. 200 psig~ min~Seco Trip Tank ____~ ~ Pit Gauge O f< Flow Monitor O~5. Gas Detectors BOPE Stack Ann~lar Preventer m ~ Pipe Rams__ _~P_~ Blind Rams ~ Ch:oke L~,e Valves ~ 0 ~~ , E~L~ LL~e VaZ~es ~ Check Valve~d Test Pressure · Test Results: Failures Remot~ O~ Blinds switch cover Kelly and Floor Safety Valves Upper Kelly'/~%_Test Pressure ~O7 Lower Ke].l~/?~_~'Test Pressure 3f~. Ball Type~''~ ~Test Pressure~ Inside BOP ~ ~Test Pressure ~0~ Choke Manifold /~ Test Pressure No. flanges~ Adjustable ~hokes _2 /P~/--- Hydrauically. operated choke Test Time ~~__hrs. 3 Repair Replacement or of failed equipment to be made within~ days and Inspector/ Commission office notified. · - -- / Distribution orig. - AO&GCC cc - Operator cc - Supervisor July 13, 1984 Mr. J. B. Kewtn Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-036 Re: Kuparuk River Unit 2B-13 ARCO Alaska, Inc. Permit No. 84-104 Sur. Loc. 1463'FSL, 597'FEL, Sec. 19, TllN, R9E, ~. Btmhole Loc. 1087'FNL, 1287'F~, Sec. 19, TllN, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be~submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereu~nder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may ~e_contact~ by a representative of the Department of Envirommentai Gonservatton. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout, prevention Mr. Jeffrey B. K~in Kuparuk River Unit 2B-13 July 13, 1984 equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commisslonmay witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly y~qurs, C. V. Chatterton Chairman of Alaska Oil and Gas Conservation .CommiSsion BY ORDER OF THE COMMISSION be Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. Post Office-m.~,-x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 5, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plats - 2B-Pad Wells 5-12, 1-4, 13-16 Dear Elaine: Enclosed are as-built location plats for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU8/L27 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany · ! NOTES; -7~ LOCATED iN PROTRACTED :SECTION 19, TOWNSHIP liN., RANGE .gE., UMIAT MERIDIAN. - o BASIS OF ELEVATION IS T~.M, 2BTI~ZB8 PER LHD~ASSOC. BASIS OF LOCATION IS TEMPORARY MONUMENTS 2B NORTH 8,2B SOUTH PER LHD&ASSOC. ORIGINAL GROUND (O.$.}ELEVAT~ONS TAKEN ON TUNDRA EAST OF WELL LOCATIONS. 0 0 DRILL TE 2 - AS ;'~UILT LOCA~ON S U'ELL i Y'5,954,9,;4.6 8 £A'2. 70 Xm 508,346 .!0 LONG .149 798 FSn 298 FEL EL. 91.9 WgLL 2 ¥=5,954,890.07 LAT. 70 Xm 508,370.93 '~NG.149 744 FSL 273 FEL EL. 92.0 W~LL 3 Y-5,954,835.49 LAT. 70 X= 508,395.79 LONG .149 689 FSL 249 FEL EL. 92.0 WELL 4 ¥=5,954,780 · 9 3 LAT. 70 X- 508,420.79 LONG.149 634 FSL 224 FEL EL. 91.9 WELL 13 Y=5 ,955 ,608.84 LAT. 70 X= 508,043.50 LONG.149 1463 FSL 597 FEL EL. 89.5 WELL lA Y=5,955,554.18 LAT. 70 X' 508,068.46 LONG.149 1408 FSL 573 FEL EL. 89.3 WELL 15 Y=5,955,499.50 LAT. ?0 X- 508,093.22 £0NG.i49 1353 FSL 548 FEL EL. 89.4 W'~LL 16 Y~5,955,445.14 LAT. 70 X- 508,117.88 LONG.149 1299 FSA 524 FEL EL. 89.2 17' !7.2395- 55' 56.8026" O.G. 87.4 ' 17' 16.7020" 55' 56.0~07" 0.0. 87.6 ' 17 '16.1649" 55 °55.3582" O.G. 87.9' 17 '15.6280" 55'54.6317" O.G. 87.6' 17'23 //.,4" 56 '05.5995" O.G. $$.4' 17'23.2374" 56'04.873E" O.G. 83.4' 17'22.6994" 56'04 .i5.!8" O.G. 82.8' 17 '22.1644" 56 '03.4370" 0.3. 82.5' "~ ~ L ~ V [~ ~ , ~~..~~ LOCATED ~N ~ROTRAOTED ~ECTION I~, ' .~? uons, Commission ~~~~ . T IIN,RgE,UMIAT MERIDIAN. . ,~ ~ ~e ~ ~c~ ~,9~ JU.~ ~.,e~i _ ..... ~ ~ ~ ~_~_~ ~RCO A~k~. nc , nfil =.ouc o. ........... · .--- ARCO Alaska, Inc. Post Office B0~.--~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 9, 1984 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2B-13 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 2B-13, along with a $100 application fee o Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plat o A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment Since we estimate spudding this well on July 25, 1984, your earliest approval will be appreciated. If you have any questions, Please call me at 263-4970. S~c~rely, /^rea Dr~l ~n§ [n§~neer dBr/d~/tw ~RUS/L39 ^ttachments RECEIVED JUL ! Alaska 0il & Gas Cons. Commlssi0n Anchora~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany la. Type of work. STATE OF ALASKA ALASKA OTL AND GAS CONSERVATION CO~IVIlSSION PERMIT TO DRILL 20 AAC 25.0O5 DRILL E~X lb. Type of well EXPLORATORY [] SERVICE [] STRATIGI~,,PHIC I_~ REDRILL [] DEVELOPMENT OIL J~X SINGLE ZONE J~( J~ DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 1463' FSL, 597' FEL, 5ec.19, TllN, R9E, UN At top of proposed producing interval 1387' FNL, 1211' FEL, Sec. 19, TllN, RgE, UN At total depth 1087' FNL, 1287' FEL, Sec. 19, TllN, RgE, UM 9. Unit or lease name Kuparuk River Unit 10. Well number 2B-13 11. Field and pool Kuparuk River Field Kuparuk River Oil Pool 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 125', PAD 89,5' ADL 25655 ALK 2581 12. Bond information (see 20AAC25.025) Federal Insurance company Type Statewide Surety and/or number //8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse miles 1/+63 feet 2B-11well 12/+' @ 2425'MD,2/+05'TV[~eet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 7179' MD, 6338' TVD fec. t 2467± 07/25/84 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 2683 psig@ 80°F Surface KICKOFF POINT 1665 feet. MAXIMUM HOLEANGLE 35 oI (see 20 AAC 25.035 (c) (2) 3080 psig@ 5993 ft. TD (TVD) SIZE Hole 24" 1 2-1/4" 8-1/2" Casing 16" 9-5/8" Weight 62.5# 36.0# 7" 26.0# Proposed Casing, CASING AND LINER Grade Coupling/ u- 0 / We H J-55 HFIERW.To/ J-SS HFIERW / _iner and Cementing Program SETTING DEPTH Length M D TOP TV D 80' 34' I 34' 2785' 34' I 34' 7146' 1 I 33' 33' ~ i i MD BOTTOM TVD 114' II 114' 2819' I 2750' I 7179' I 6338' I I QUANTITY OF CEMENT (include stage data) ± 200 cf 800 sx Cold Set ill & 250 sx Cold Set II 300 sx Class "G" 22. Describe proposed program: ARCO Alaska, Inc., proposes t,o drill a Kuparuk River Field development well to approximat,ely 7179' HD (6338' TVD). Select. ed intervals will be logged, A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe, It will be tested upon installat,ion and weekly thereafter, Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2683 psi, Pressure calculations are based on virgin reservoir pressure, Surface pressure is calculat,ed wit,h an unexpanded gas bubble at surface, including temperature effects, Casing will be tested 'co 2000 psi prior t,o releasing t,he drilling rig, Non-freezing fluids will be left in uncemented annuli through the permafrost int,erval, 2B-13 will be 124' away from 2B-11 2405'TVD. There are no closer wellbores anywhere downhole, Reserve pit, fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left, wit,h a non-freezing fluid during any (see attached sheet) 23. I hereby cer.,t,~that the foregoing is true and correct to the best of my knowledge SIGNED /J TITLE Area Drilling Engineer' T hespace~Jiss~onusm coNDITIONS OF APPROVAL Samples required [-]YES Permit number APPROVED B Form 10-401 GRU8/PD14 Mud log required []YES [~0 Approval date DATE Directional Survey required [~YES I--INO JAPI number 50- ot.,q-'z.~ I$~ SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE July 13, 1984 by order of the Commission Submit in triplicate Permit to Drill 2B-13 interruptions in the disposal process. The well will be completed by the workover rig using 3-1/2", 9.2#/ft, J-55, 8rd tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety Valve will be installed and tested upon conclusion of the job. ........... ~_0oo _ UI~--F-[EL_D_~[ NO_R!H' St~OPE,- ALA.__~_A __1~. N ',,{Hi!Or I~C., ~: TYD- ] 49_5 KOP- TVD~-1665 TIgD=1665 D£P=O TOP UGNU SNDS TVD=1805 TI91~=1805 DEP~5 2, TOP U SAK SND9 TVDm2350 T~-2~6 OEP-12? ~ K-~2 TVD=27~O T~-275~ DEP=30~' '~ AVERAGE ANGLE 34-~EG 37 ') iooo ooo PAD 2B. WELL NO, 13 PROPOSED KUPARUK FIELD. NORTH SLOPE. ALASKA EASTMAN WHIPSTOCK. INC. 2000 40.00 _. _ ;30.00 _ 21300. - ........................ -T.--_ _1 ODD. _ WEST-EAST 1 000 0 1 000 l I FARGE:T CENTEIt TVD=59~t TIID=6757 TA~ LOC~,.TT ON ~ 1320! FNL. 1228' ;'EL SEC. i19. Tll#. Rg~ .~~ (LOG'GINS PT> 140~ TH 24,9,Z WEST I . I SUR~AC~ i SEC. 19. T11N. RgE i2575' (To TARGET) ....... ARCO ~ALASKA. ~INC. PAD 2B. WELL NOi 13-14-15-16 PROPOSED KUPARUK FIELD. NORTH SLOPE. ALASKA EASTMt, N WHISPTOCK. INC. , ! NOTE' WELL PATHS EXTEND BEYOND ND R T'H THIS VIEWING WIND01~ ~oo Boo ~'oo 600 , ~oo 4oo ~oo ~oo ~oo oo O0 ..... m ~ ~ ~- , ~ ~8 O0 .._ , . . ............ ~ .......... 702 .... 1623 , , 541 I ~55 ,00 ....~ , , ~ ~'~,.: ~ , . ~ PREYE~TE~ PIPE 8 BLIND ' ~ - 4 DIAGRAM ~1 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting head 2. 11" - 3000 psi casing head 3. 11" - 3000 psi x 13-5/8" - 5000 psi spacer spool 4. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 5, 13-5/B" - 5000 psi pipe rams 6. 13-5/8" - 5000 psi drilling spool w/choke and kill lines 7. 13-5/8" - 500D psi pipe rams 8. 13-5/8" - 50DO psi blind rams 9. 13-5/8" - 5000 psi annular ACCUMULATOR CAPACITY TEST '1. CHECK AND FILL ACCUMULATOR RESERVOIR TD PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON NADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS IN HF. gJ). 3. CLOSE ANNULAR PREVENTER AND ¥'ALVES UPS~ OF C}-IOKES. DON-~T TEST AGAINST CLOSF_f) CHOKES. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR i0 B. ~.~'PRESSURE DOWNSTRKAM OF CHOKE ISOLATION VALV~S~ TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD.VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAJM. BLEED SYSTEM TO ZERO PSI. 9. OPEN TOP SET OF PiPE RAMS AND CLOSE BOTTOM SET OF PIPE RAMS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 I~INUTES BLEED TO ZERO PSI. 11. OPEN BOTTOM SET OF PIPE RAMS. BACK OFF RUNNING jOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSi WITH KOOMEY PUMP. 15. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 16. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. RECEIVED JUL 1 0 BB~ Alaska Oil & Gas Cons. Commission Anchorage Surface Diverter System 1. 16"-2000 psi Tankco starting head. 2. Tankco quick connect assy. ~6" X-20" 2000 psi double studded adapter. 4. 20" 2000 psi drilling spool w/lO" side outlets. 5. 10" ball valves, hydraulically actuated, w/10" lines to reserve pit. Valves to open automatically upon closure of annular preventer. 6. 20" 2000 psi annular preventer. 7. 20" bell nipple. h Maintenance & 0Deration 1. Upon initial installation close annular preventer and verify Ehat ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. 3. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually override and close ball valve to upwind diverter line. Do not shut in well under any circumstances. 16" Conductor RECEIVED JUL .l 0 Alaska 011 & Gas Cons. Commission Anchorage CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee 7 <2) Loc thr~ 8~' ,HZ# (8~? (1,0 and 11) (12 thru 20) . 10. 11. YES NO 1. Is the permit fee attached .......... ................................ 2. Is well to be.located in a defined pool ............................. 3. Is well located proper distance from property line ................... __ 4. Is well located proper distance from other wells ................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is well bore plat included ............... 7. Is operator the only affected party ................................... 8. Can permit be approved before ten-day wait .......................... ~f~ Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... 12. Is conductor string provided ....................................... 13. Is enough cement used to circulate on conductor and surface 14. Will cement tie in surface and intermediate or production strings ... 15. Will cement cover all known productive horizons ..................... 16. Will surface casing protect fresh water zones .............. 17. Will all casing give adequate safety in collapse, tension and burst.. 18. Is this well to be kicked off from an existing wellbore ............. 19. Is old wellbore abandonment procedure included on 10-403 ............ 20. Is adequate well bore separation proposed ........................... REMARKS (21 thru 24) 21. 22. 23. 24. Is a diverter system required ....................................... ~jr~ .__ Are necessary diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating- Test to [,~Z,, ~57f}.~' psig Does the choke manifold comply w/API RP-53 (Feb.78) .................. (6) Add: 25. Additional requirements ............................................. ~ o,~'.~ ~1 ~ Additional Remarks: ('-Z~__~ 7- /]~P~.~, t~'~-.f/ /~ ,/,,~, 7~.~. ~-// ~ ( I Geology: Engi~ering: HWK ~2 LCS~~EW WVA JK~~_~HJH JAL~ .... MTI~" .~' rev: 12/08/83 6.CKLT INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE 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. bis TAPE VERIFICATION ,blSTiMG LVP OIO,H02 UERIFICATIBN [.,ISTING PAGF, ** REEl., N~ADER ** SERVICE NAME :EDIT DATE :84110t21 ORIGIN : REEL NAME CONTINUATION # :01 PREVIOUS REEL : COMNENTS : ** TAPE HEADER SERVICE NA~E :EDIT DATE ~84/10/~1 ORIGIN :0000 TAPE NAME :9591. CONTINI~ATION # :01 PREVIOUS TAPE C[)M~ENTS : ** RECORD TYPE 137 ** ** FILE HEADER ** FILE NAME :EDIT ,001 SERVICE NAME VERSION # : DATE : MAXIMU~ LENGTH : 1024 FILE TYPE : PREVIOUS f'ILE : ** IN~[,RMATIf]N RECORDS CONTENTS UNIT TYPE CATE SIZE CODE CN : ARCO ALASKA INC WN j 2B-13 FN ~ KUPARUK RANG: 9E TOWN: llN S,ECT~ COUN~ N,SLOPE $TAT{ ALASKA CTRY: ,USA 000 000 0~6 ~5 000 000 0 6 5 000 000 OOB 065 000 000 002 065 000 000 004 065 000 000 002 065 000 000 012 065 000 000 006 065 000 000 003 065 SCHLUMBERGER hVP 010,H02 VERIFICATION LISTING PAGE 2 ALASKA DIVISION COMPUTING CENTER : CO~4PANY = ARCh A[.,ASKA WELL = 2B-13 FIELD = KUPARUK COUNTY = N,SLOPE STATE = ALASK SECTION = ! 9 TOWNSHIP -- llM RANGE = 9E TAPE DENSITY = 800 BPI 69591 BASE LOG: DIL , RUN # ! DATE bOGGED 3 OCT 84 BOTTOM LOG INTERVAL : 7074 ET, TOP LOG INTERVAL m 2805 FT CASING-LOGGER : 9 625 I'~, @ 2805 FT BIT SIZE = B:500 IN. ' TYPE HOLE FLUID m LOW SOLIDS NO~ DISPERSED DENSITY : 10,10 VISCOSITY : 40,00 bVP 010,H02 VERIFICATION LISTING PAGE 3 FLUID LOSS RM @ SEAS, TEMP, R~F ~ SEAS, TEMP, RMC m ~EAS' TE~P, RM ~ BHT MATRIX : 9 O0 = 5i80 : 2, 90 ~ 64 F : 2,760 @ 66 F : 2,140 @ 68 F : 1 349 ~ 145 F m SANDSTONE ** DATA FORMAT RECORD ** ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 2 1 66 0 4 1 66 1 8 4 73 6O 9 4 65 ,lin 16 I 66 0 1 66 0 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT API AP1 AP1 AP1 FILE SIZE SPL REPR ID ORDER ~ LOG TYPE CLASS MOD NO, DEPT FT O0 000 O0 0 0 4 SFLU DIL OHMM O0 220 O1 0 0 4 ILD DI[, OHMS O0 120 46 0 0 4 I~M DIL O.M~ O0 120 44 0 0 4 8P DIb MV O0 010 01 0 0 DI5 GAPI O0 310 O1 0 0 4 GR FDN GAPl O0 ~10 Ol 0 0 4 CALI FDN IN O0 280 O1 0 0 4 R.o~ ~. ~/c~ oo ~so o~ o o 4 DRHO FD" G/C3 O0 356 O! 0 0 4 NRAT FDN O0 420 01 0 0 4 R.~ ~o. oooooooo o .~.x ~ ~u OD~o ooo o 0 0 0 4 FCNL FDN CPS O0 0 0 4 PROCESS CODE (OCTAL) 1 68 00000000000000 ! 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000~000 ! 68 00000000000 O0 I 68 0000000000 O0 I 68 00000000000000 X 68 00000000000000 I 68 00000000000000 1 68 00000000000000 I 68 0000 O0 0 1 68 0000~ §000000 O0 0000 0 I 68 00000000000000 1 68 00000000000000 ** DATA ** DE.PT 7105,5000 SFLU 2,4727 2,4375 ILS 2,3555 LVP 010,H02 VERIFICATION LISTING PAGE 4 SP RHOB NPHI OEPT SP RHOB NPHI -16,7813 GR ~6 2,3'730 DRHO 0 33,6426 NCNL 1090 7~00 0000 SFLU 2 15:7500 GR 46 2,]730 DRHO -0 35.4980 NCNb 1090 DEPT 7000,0000 SFLU 2 SP -21.0469 GR 100 RHOB 2.3965 DRMO 0 NPHI 44~ 0918 NCNL 2140 DEPT RHOB NPHI SP RHOB NPHI DEPT RMOB NPHi DEPT RHOB NPHI DEPT SP RHOB NPHi DEPT RHOB NPHI .DEPT S P R H 0 B NPH I ,6563 GR ,0811 NRAT ,0000 FCNL D:EPT RHOB: NPHI ,5117 ,6563 ,0811 NRAT .0000 FCNL 4707 lED i3750 GR 1904 NRAT ,0000 FCNL 6~00 0000 SFLU 3 23:0000 GR 104 2 429~ DRHO 0 40~478 NCNb 1882 ,3164 ILD ,5000 GR ,0103 NRAT ,0000 FCNb 6800.0000 SFLU 8 -30,8281 GR 89 2.3613 DRHO 0 31.2988 NCNb 2420 .8203 ILD ,5000 GR ,0107 NRAT ,0000 FCNL 6700,0000 SFLU 3 3,8 25 ,,R 98 '32,4 55 DRHO 0 33,1543 NCNL 2164 ,9570 1LD ,5000 GR ,0249 NRAT ,0000 FCNL 6600 0000 SFLO 1, ,1875 GR 130 2,3945 DRHO 0 41,5039 NCNL i744 9004 ILD 750 GR ~288 NRAT 0000 FCNL 6.500, ~000 SFLU 2 36, 063 GR 132 4,4102 DRHO 0 4 ,8730 NCNb 1.781 ,83574 IL.D , 750 GR * FCNh 6400,0000 SFLU 3 DRHO -0 41.', 3086 NCN.L 1920 0879 , N R,AT ,0000 FCNL 6300,0000 SFLU ~42,21'87 GR -999,2500 DRHO -999,2500 NCNb 23,7441 35,6250 ~R -999,2500 NRAT -999,2500 FCNI, 6 00,0000 .$~b.) 51,5000 GR '999,2500 DRMO -999,2500 NCNL 3,9727 IbD '.,999, 5 0 NRAT -999,2500 FCNL 2 85 372 2500 2.4355 46.6563 2,9785 372.2500 2,3477 100,3750 3,4746 607,0000 2,4961 104,5000 3,3984 600,0000 8,1328 89,5000 2,8555 879,5000 98. O0 2,9941 751'5000 5127 131,53750 527 49~'7500, 2,0098 132. 8750 s oo 2,2246 23~,7500 547 '4785 ,0000 2.6465 235.6250 -999,2500 -999,2500 3,1211 .126, 500 99:9,~250 -999.~500 CALI RNRA I L, bi CALl RNRA CALI RNRA I bM C A I., I RNRA IbM CALI RNRA Ib~l CALI R NRA CALX RNRA IbM CALl RNRA CALl R N R A I L N CALl RNRA CALl RN'R~ B,5000 2,9277 ,3945 ,0938 2,9277 2,4160 ,5352 ,5254 2,6191 9,0625 3,1348 7,7891 8,8594 2,7578 1,6104 10,27~4 3,53i3 2,3418 9,~000 3, 098 ' , ,'2500 3,3203 99~'6953 - .2500 5VP OlO,H02 VERIFICATION LISTING PAGE 5 DEPT 6100,0000 SFLU 8P -52,4375 GR 110, RHOB -999,2500 DRHO -999, NPHI -999.2500 NCNb 'q DEPT 60.00.0000 SFLO ~, SP 47,3750 GR 12 . RHOB -999,2500 DRHO -999, NPHI -999,2500 NCNL -999, DEPT 5900,0000 SFLU SP -44.8437 GR 149, RHOB -999 2500 DRHO -999, NP~I -999:2500 NCNb -999, DEPT 5800 0000 SFLU 3, SP -53:0313 GR 130, RHOB -999:2500 DRHO -999, NPHI -999 2500 NCNb -g9g, DEPT 5700,0000 SFLU 2, SP '49.6563 GR 111, RHOB -999,2500 DRHO -999, NPHI -999,2500 NCNb -999. D£PT 5600,0000 SFLU SP -52,2500 Gfl 93, RHOB -999,2500 DRHO -999, NPH! -999,2500 NCNb -999, 7930 1875 2500 2500 4961 6250 2500 2500 5508 2500 2500 2500 0918 O0 2500 84 2500 2500 5703 4375 2500 2500 NRAT FCNL IbD GR NRAT FCNL GR NRAT FCNL GR NRAT FCNL IbD NRAT FCNL GR NRAT FCNL DEPT 5.50507,0000 SFLU 4,~82~8=~ RHOB 2999,2500 DRHO -999 2500 NPMI 999,2500 NCNb -999: ~500 FCNL 4570 6250 2500 2500 500 500 DEPT 5400,0000 SFLU 3, SP -63,~938 GR 1~94. RHOB '999, 500 DRHO -9 NPHI -999,2500 NCNb '999, DEPT 5300,0000 SFLU ~, 8P -50,0938 OR 160, RHOB -999,2500 DRHO -999, NPHI '999,~5'00 NCNb -999, DEPT 5,~00,0000 SFLU 4. RHOB - .. ,250o DRHO -999, NPHI -999,2500 NCNb -999, DEPT 5.100.0000 SFLU 1, SP '-48,3750 GR 134, RHOB 999,2500 DRHO NPHI -999,2500 NCNb 3477 2500 250o 250o 94 4 0o'~o 2500 2500 ILD GR NRAT FCNL hD R NRAT FCNL GR NRAT FCNL ILD NRAT FCNL 4.1562 110.1875 :999 2500 999:2500 3,6895 120,6250 '999,2500 "999.2500 2 1992 149~2500 -999,2500 -999,2500 3,3945 130,2500 '999,2500 '999,2500 2 9648 111:6250 -999.]590 -999. 5 0 3.1582 '999, 50 -999,2500 -999,2500 -999,2500 3,1699 '999:~500 -999 0 '999.~80 :999. oo 999. O0 4,3281 ~999,2500 999,2500 '999.2500 , 1973 -99 .2500 '999.2500 '099.2500 CALl RNRA IbM CALl RNRA IbM CAbI RNRA IbM CALI RNRA IbM CALl RNRA I .L 1~ CAL! RNRA IbM CALl I LN C A b I RNRA IbM CALI R~RA CALl RNRA IbM CALI RNRA 4,2852 10.2891 -999,2500 3,7383 9,7656 -999,2500 2,1738 9.3828 -999,2500 3,3730 10.2891 -999,.2500 2 9785 9!8750 -999 2500 9, -999,.2500 ~594 500 -999'.2500 3,1992 -99~,2500 '99 ,2500 ,4336 ,9992,2500 -999,2500 4,3086 '9999,2500 -.99 . 2500 2,~367 -999, 500 -999,2500 LVP OlO,H02 VERIFICATION LISTING PAGE 6 DEPT 5000 0000 SFLU SP --51:6875 GR RHO8 999,2500 DRHO NPHI -999,2500 NCNL DEPT 4~00 0000 SFLO SP -55~6563 GR RHOB -999,2500 ORHO NPHI -999,2500 NCNb DEPT 4800.0000 SFLU SP -50.3438 GR RHOB 999,2500 DRHO NPH! :999,2500 NCNb DEPT 4700 0000 SFLU SP -49~4063 GR RHOB 999 2500 DRHO .pHI 2999: So0 NCNb DEPT 4600 0000 SF[.U - . 9,5313 GR ,2500 DRHO NPHI '999.2500 NCNb ~PT 4500.0000 SFLU '51,4375 GR RHOB -999,~500 DRHO ~PHI -999, 500 NCNL DEPT 1400.~000 SF[.U SP -55, 813 GR ~HOB 999.~500 DRHO NP~I -999,2500 ,NCNL DEPT 430~,0000 SFLU SP -5;,4063 GR RHOB -999,2500 DRHO NPHI -999,2500 NCNb DEPT 4200.0000 SFLU SP -55,3438 GR RHOB .999.2500 DRHO NPHI -999,2500 NCN[~ DEPT 4100,~000 SFLU ~SP -57, 000 GR RMOB -999,2500 DRHO NPHI -999.2500 NCNb DEPT 4~00,0000 SFLU 2.9590 !I~D 120,6250 GR -999,2500 NRAT -999,2500 FCNL 3,3730 ILD {25.4375 GR -999 2500 NRAT -999:2500 FCNL 3.1074 ILD 108,4375 GR -999,2500 NRAT -999,~500 FCND 4,0430 IbD 101,1250 GR T -999,2500 NRA -999,2500 FCNL 2,537~ 1~,4375 G~ -9 .2500 NRAT -999,2500 FCNL 2,3516 104,4375 GR -999,2500 NRAT -999.2500 FCNL 2,3633 1~ 8750 GR -9 :2500 NRA~" -999~2500 FCNL 2,3750 113,7500 GE 500 NRAT -999, 1500 FCNL ~999, 2 3457 10~ 5625 -999 2500 NRAT -999 2500 FCNL 2,7324 -999,2500 -999.2500 -999,2500 3,3164 -999,2500 999 2500 3,0625 -999,2500 '999,2500 '999.2500 3,5605 '999,2500 '999,2500 '999,2500 2.6113 "999.2500 '999'2500 '999,~500 2.4609 '999,2500 '999,~500 -g99. 500 2,4902 -999,2500 -999,2500 -999,2500 2,~84 -999, 500 '999,~5 -999, O0 2 6289 -999.2500 -999.2500 IbM CALI RNRA IbM CALI RNRA IbM CALI RNRA IbM CALl RNRA ILM CALl RNRA CALI RNRA CAL! RNRA CAbI RNRA I i:, M CAbI RNRA 2,4219 ILD . 2.7207 IbM 103,3125 GR 999~2500 CALI -999,2500 NRAT -999,2500 RNRA -999,2500 FC~L -999.2500 2,6816 -999,2500 -999,2500 2,~551 ILD 10~, 375 GE -99 ,2500 N'~A~ CALl RNRA 2.7422 :999,2500 999,2500 3.3223 -999,2500 -999,2500 3 0~76 -999:2500 -999,2500 3 5762 -999,2500 2,589~ -999~2500 -999,2500 :ggg: ggg 9,2500 2 ~338 -999:500 -999,2500 .99~'4531 999*2500 - .2500 -999, O0 -999,2500 -999.25 -999.2500 2,6055 '999,~500 -999. 500 hVP 010,H02 VERIFICATION LISTING PAGE 7 NPHI -999,2500 NCNb DEPT 3900.0000 SFLU SP -62,3750 GR RMOB 999,2500 DRHO NPHI ~999. 2500 NCNL DEPT 3800,0000 SFLU SP 66 6250 GR RHOB -;99i2500 DRHO NPH! -999 2500 NCNL DEPT 3!00.0000 SFbU SP 68'6250 GR RHOB -999,2500 DRHO NPHI -999,2500 NCNL DEPT 3600,0000 SFLU SP -66,1875 GR RHOB -999.2500 DRHO NPH! -999,2500 NCNb DEPT 35.009,0000 SFbU SP ~ 6 , 1250 GR RHOB :999,2500 D~HO NPNI 999,2500 NCNb DEPT 3400 0000 SFLU SP -68:8125 GR RHOB -999,2500 DRHO NPHI -999,2500 NCNb DEPT 3300,0000 SFLU SP -70.,875 GR RHOBNpH! '999.99-9 ,25g0 DR,O . ,25 0 NCNb DE:PT 3~ 0~,0000 S~'t,,U $.P ~8 ,5625 GR RHOB 99 1,2500 DRHU NPHI 999,2500 NCNb .DEPT 3100,~000 SFLU SP -88, 000 GR .RHOB -999,2500 DR}~O N'PHI -999,2500 NCNb DEPT 3000,0000 SFbU Sp -93,7500 GR RMOB -999,2500 DRHO NPH! -999,2500 NCNb DEPT 2900,00~0 SFbU SP -81.87 0 GR -999,2500 FCNL 3 0547 ILD 96' ,2500 GR -999,2500 ~RAT -999~2500 FCNL 2,9941 ILD 114,8125 GR -999,2500 -999,2500 FCNL 4,5508 ILD 103,0000 '999,2500 NRAT -999,~500 FCNL 2,7910 95,6875 GR :999,2500 NRAT 999,2500 FCNL 1~,3047 ILD 8 ,9375 GR '999,2500 NRAT -999,2500 FCNL 3,1035 ILD 99,3750 -999,~500 NRAT '999,2500 FCNL 2 8711 ILD 99~0625 GR -999,2500 ~RAT '999.2500 FCML 3,6230 ILl) I07,8750 -999~500 NRAT -999,2500 FCNL 8,0313 ILD 88.8750 OR -999,2500 HRAT '999,2500 FCNL 7 5234 I. bD 70 6250 GR -999 2500 NRAT -999 2500 FCNb 4,~414 ILD 79,. 000 GR '999,2500 3.1~b5 Ib~ -999,2500 CALl -999,2500 RMRA -999,2500 3.2754 -999,2500 CALl -999,2500 RNRA -999,2500 4,1719 -999,2500 CALl -999 2500 RNRA -g99:2500 3,5957 -999,2500 CALl -999.2500 RMRA -999,2500 10 0781 .Ib~ -999:2500 CALl -999 2500 RNRA -999:~500 3,,5293 Ib~ -999,2500 CALl -999,~500 RNRA -999.2500 .3,2363 IbM -999.2500 CALl -99~,2500 RNRA -99 ,~500 3,6875 IL~ '999.2~0 CALl - 999,2 0 RNR A -999,2500 7,7656 IL~ -999,2500 CALl -999,2500 RNRA -999.2500 8,0156 IL~ '999,~500 CALl :999, 500 RNRA 999,2500 6,9766 Ib~ '999.2500 CALl -999 0 -999 2500 3,1133 -999,2500 -999,2500 4,0820 :999,2500 999,.2500 3.2441 -999.2500 -999'2500 8,]656 ,'999. 500 '999'2500 3 3457 -999:2500 -999,2500 3.0586 '999.2500 -999,2500 3,5586 :999,2500 999,~500 7,6719 :999,2500 999,2500 7,789! '999~.2500 ,2500 .99~ '0273 .2500 LVP OlO,H02 VERIFICATION [.,IS'rING PAGg 8 RHOB 999,2500 DRWO -999,2500 NRAT NPHI ~999.2500 NCNL -999,2500 FCNL DEPT 2800.0000 SFLU SP -78,1575 GR RHOB -999,2500 DRHO NPHI -999.2500 NCNL 2000 0000 ILO 61i0000 GR '999 2500 NRAT -999,2500 FCNL DEPT 2795,0000 SFi, U SP '77.0000 GR RHOB 999.2500 DRHO MPHI -~999.2500 NCNb 2000 0000 ]LD 66" .6250 GR -999,2500 NRAT -999,2500 FCN[. ** FILE TRAILER FI.bE NAME :EDIT ,001 SERVICE NAME VERSION # DATE : ~AXI~U~ LENGTH : 1024 NEXT FILE NA~E : RECORD TYPE 137 ** -999,2500 RNRA -999.~500 1! 5234 IL~ -999i2500 CALI -999 2500 RNRA -999.2500 14,4375 -99q,2500 CALI -999,2500 RNRA -999,2500 -999,2500 2000,0000 -999,2500 -999,2500 O00iO000 999 2500 999 2500 ** TAPE TRAILER SERVICE NAME :EDIT DATE :84/10/21 ORIGIN :0000 TAPE NA~E :9591 CONTINUATION ~ :01 NEXT TAPE NAMe] COMMENTS : · ** REEL TRAILER ** SERVIC'E NAME :.EDIT DATE :84/10/2~ ORIGIN : REEL NAME : CONTINUATION # :01 NEXT REEL NAME : COMMENTS : ** RECORD TYPE 137 ** RECORD TYPE 137 ********** ~OF ********** EOF
