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Home My WebLink About195-092MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2T-28 KUPARUK RIV UNIT 2T-28 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2025 2T-28 50-103-20225-00-00 195-092-0 W SPT 5705 1950920 3000 2680 2680 2680 2680 55 55 55 55 REQVAR P Adam Earl 6/21/2025 MIT-IA tested as per AIO 2B.066 to max. ant,inj.psi 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2T-28 Inspection Date: Tubing OA Packer Depth 1350 3400 3300 3300IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE250625074256 BBL Pumped:3 BBL Returned:3.1 Tuesday, July 22, 2025 Page 1 of 1             ORIGINATED TRANSMITTAL DATE: 8/8/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 4957 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 4957 2T-28 50103202250000 Injection Profile (IPROF) 27-Jul-2024 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 tom.osterkamp@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 195-092 T39386 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.08 13:27:28 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com tom.osterkamp@conocophillips.com MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 27, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2T-28 KUPARUK RIV UNIT 2T-28 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 2T-28 50-103-20225-00-00 195-092-0 W SPT 5705 1950920 3000 2720 2720 2720 2720 70 80 80 80 REQVAR P Guy Cook 6/10/2023 MITIA to maximum anticipated injection pressure per AIO 2B.066. Testing was completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2T-28 Inspection Date: Tubing OA Packer Depth 1570 3500 3410 3380IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC230609155226 BBL Pumped:3 BBL Returned:2.9 Thursday, July 27, 2023 Page 1 of 1            1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Conductor Ext ConocoPhillips Alaska, Inc.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 10890'feet NA feet true vertical 6058'feet NA feet Effective Depth measured NA feet 10354'feet true vertical NA feet 5705'feet Perforation depth Measured depth 10473'-10628' feet True Vertical depth 5793'-5908' feet Tubing (size, grade, measured and true vertical depth)3 1/2" L-80 10382' 5726' Packers and SSSV (type, measured and true vertical depth)Baker SAB-3 10354' 5705' 12. Stimulation or cement squeeze summary:N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: 8/21/2021 Contact Phone: 195-092 50-103-20225-00-00 ADL002548 KRU 2T-28 P.O. Box 100630, Anchorage, Alaska 99508 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Operator Name 4. Well Class Before Work:5. Permit to Drill Number: Packer measured true vertical Casing Length Size MD TVD N/A Kuparuk River/Kuparuk River Oil Plugs measured Junk measured Burst Collapse Conductor 81'16"121' 121' Intermediate Surface 4233'9 5/8" 4274'2892' Liner Production 10846'7"10884'6100' NA NA NA NA NA N/A Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 321-340 Authorized Name: Authorized Signature with date: Senior Engineer:Senior Res. Engineer: 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283 WINJ WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Roger Mouser / Roger Winter n1927@conocophillips.com 659-7506 Well Integrity Field Supervisor NA NA NA NA NA ntt e Fra O g g g l g y e 6. A y G L PG AAC 25 R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 8:43 am, Aug 23, 2021 Digitally signed by Roger Winter DN: CN=Roger Winter, E=n1927@conocophillips.com, C=US Reason: I am the author of this document Location: your signing location here Date: 2021.08.21 14:43:35-08'00' Foxit PhantomPDF Version: 10.1.3 Roger Winter RBDMS HEW 8/25/2021 SFD 8/23/2021DSR-8/23/21VTL 9/9/21 SFD 8/23/2021ADL 025569, P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 21 Aug 2021 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. Well KRU 2T-28 (PTD 195-092) conductor extension Sundry # 321-340. Summary: Conductor has been extended to cover the surface casing. Please contact Roger Winter or Roger Mouser at 659-7506 if you have any questions. Sincerely, Roger Winter Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. Digitally signed by Roger Winter DN: CN=Roger Winter, E=n1927@conocophillips.com, C=US Reason: I am the author of this document Location: your signing location here Date: 2021.08.21 14:42:54-08'00' Foxit PhantomPDF Version: 10.1.3 Roger Winter Date Event Summary Executive Summary Extend conductor 08/08/21 Prep conductor for extension 08/17/21 Weld extension on conductor to cover surface casing Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB (Est. 58' of Fill) 10,570.0 3/12/2020 2T-28 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Updated Tag Depth 3/12/2020 2T-28 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 40.5 Set Depth (ftKB) 121.0 Set Depth (TVD) … 121.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 41.1 Set Depth (ftKB) 4,274.0 Set Depth (TVD) … 2,891.7 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 38.4 Set Depth (ftKB) 10,883.9 Set Depth (TVD) … 6,100.5 Wt/Len (l… 26.00 Grade L-80 Top Thread BTC-MOD Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 37.0 Set Depth (ft… 10,382.4 Set Depth (TVD) (… 5,726.0 Wt (lb/ft) 9.30 Grade L-80 Top Connection ABM-EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 37.0 37.0 0.00 HANGER FMC GEN IV TUBING HANGER 3.500 517.9 517.7 3.32 NIPPLE CAMCO DS LANDING NIPPLE NO GO 2.812 10,346.4 5,699.5 42.70 NIPPLE CAMCO W-1 SELECTIVE LANDING NIPPLE 2.812 10,354.4 5,705.4 42.69 PACKER BAKER SAB-3 PACKER w/ K-22 ANCHOR SEAL ASSEMBLY 3.250 10,370.5 5,717.2 42.67 NIPPLE CAMCO D NIPPLE NO GO 2.795" NO GO 2.750 10,381.5 5,725.3 42.66 SOS BAKER SHEAR OUT SUB 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 336.0 336.0 0.75 LEAK - SURFACE CASING SCLD--OA leak found @ 336', Initial T/I/O= 2630/760/50 9/21/2011 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 10,473.0 10,493.0 5,792.7 5,807.4 C-4, 2T-28 9/11/1995 4.0 IPERF Zero° phasing; Oriented Zero°; 2 1/8" Enerjet 10,534.0 10,562.0 5,837.8 5,858.6 A-4, A-3, 2T-28 9/11/1995 4.0 IPERF Zero° phasing; Oriented Zero°; 2 1/8" Enerjet 10,590.0 10,608.0 5,879.4 5,892.8 A-2, 2T-28 9/11/1995 4.0 IPERF Zero° phasing; Oriented Zero°; 2 1/8" Enerjet 10,616.0 10,628.0 5,898.8 5,907.7 A-2, 2T-28 9/11/1995 4.0 IPERF Zero° phasing; Oriented Zero°; 2 1/8" Enerjet Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 10,300.9 5,666.1 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/13/1995 Notes: General & Safety End Date Annotation 8/20/2011 NOTE: WELDED 18" TALL, .375" CONDUCTOR EXTENSION IN PLACE 11/24/2010 NOTE: View Schematic w/ Alaska Schematic9.0 2T-28, 3/12/2020 8:07:56 PM Vertical schematic (actual) PRODUCTION; 38.4-10,883.9 IPERF; 10,616.0-10,628.0 IPERF; 10,590.0-10,608.0 IPERF; 10,534.0-10,562.0 IPERF; 10,473.0-10,493.0 SOS; 10,381.5 NIPPLE; 10,370.5 PACKER; 10,354.4 NIPPLE; 10,346.4 GAS LIFT; 10,300.9 SURFACE; 41.1-4,274.0 NIPPLE; 517.9 LEAK - SURFACE CASING; 336.0 CONDUCTOR; 40.5-121.0 HANGER; 37.0 KUP INJ KB-Grd (ft) Rig Release Date 8/31/1995 2T-28 ... TD Act Btm (ftKB) 10,890.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032022500 Wellbore Status INJ Max Angle & MD Incl (°) 67.64 MD (ftKB) 2,875.00 WELLNAME WELLBORE2T-28 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name:4. Current Well Class:5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6.API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Will planned perforations require a spacing exception?Yes No KRU 2T-28 9. Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 10890' Casing Collapse Conductor Surface Production Packers and SSSV Type:PKR:Packers and SSSV MD (ft) and TVD (ft):PKR: SSSV:SSSV: 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date:7/7/2021 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Well Integrity Field Supervisor Roger Mouser / Roger Winter n1927@conocophillips.com 10846' 121'121' 10884' 81'16" 9 5/8" 7" 4233' Length TVD Burst 10382' MD 2892' 6100' 4274' 6105' PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025548 195-092 P.O. Box 100630, Anchorage, Alaska 99508 5010320225-0000 ConocoPhillips Alaska, Inc. Kuparuk River/Kuparuk River Oil COMMISSION USE ONLY Authorized Name: Tubing Grade:Tubing MD (ft): 5793'-5908' Perforation Depth TVD (ft):Tubing Size: 10473'-10628' Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 659-7506 Baker SAB-3 N/A MD 10354' TVD 5705' N/A Size Authorized Signature: 7/21/2021 3 1/2" Perforation Depth MD (ft): L-80 m n P s 66 t y t _ c Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 10:52 am, Jul 07, 2021 321-340 Digitally signed by Roger Winter DN: CN=Roger Winter, E=n1927@conocophillips.com, C=US Reason: I am the author of this document Location: your signing location here Date: 2021.07.07 07:05:46-08'00' Foxit PhantomPDF Version: 10.1.3 Roger Winter X 50-103-20225-00-00 SFD 7/7/2021 X Photo document pre and post extension ext conductor 10-404 DSR-7/9/21 6058' VTL 7/14/21 SFD 7/7/2021 JLC 7/14/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.14 12:48:33 -08'00' RBDMS HEW 7/14/2021 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 07 July 2021 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. Well KRU 2T-28 (PTD 195-092) to extend conductor. Summary: Conductor has subsided or well has grown 7” or more so we would like to add conductor to cover the surface casing. Please contact Roger Winter or Roger Mouser at 659-7506 if you have any questions. Sincerely, Roger Winter Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. Digitally signed by Roger Winter DN: CN=Roger Winter, E=n1927@conocophillips.com, C=US Reason: I am the author of this document Location: your signing location here Date: 2021.07.07 07:05:26-08'00' Foxit PhantomPDF Version: 10.1.3 Roger Winter Conductor has subsided or well has grown 7” or more Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB (Est. 58' of Fill) 10,570.0 3/12/2020 2T-28 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Updated Tag Depth 3/12/2020 2T-28 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 40.5 Set Depth (ftKB) 121.0 Set Depth (TVD) … 121.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 41.1 Set Depth (ftKB) 4,274.0 Set Depth (TVD) … 2,891.7 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 38.4 Set Depth (ftKB) 10,883.9 Set Depth (TVD) … 6,100.5 Wt/Len (l… 26.00 Grade L-80 Top Thread BTC-MOD Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 37.0 Set Depth (ft… 10,382.4 Set Depth (TVD) (… 5,726.0 Wt (lb/ft) 9.30 Grade L-80 Top Connection ABM-EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 37.0 37.0 0.00 HANGER FMC GEN IV TUBING HANGER 3.500 517.9 517.7 3.32 NIPPLE CAMCO DS LANDING NIPPLE NO GO 2.812 10,346.4 5,699.5 42.70 NIPPLE CAMCO W-1 SELECTIVE LANDING NIPPLE 2.812 10,354.4 5,705.4 42.69 PACKER BAKER SAB-3 PACKER w/ K-22 ANCHOR SEAL ASSEMBLY 3.250 10,370.5 5,717.2 42.67 NIPPLE CAMCO D NIPPLE NO GO 2.795" NO GO 2.750 10,381.5 5,725.3 42.66 SOS BAKER SHEAR OUT SUB 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 336.0 336.0 0.75 LEAK - SURFACE CASING SCLD--OA leak found @ 336', Initial T/I/O= 2630/760/50 9/21/2011 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 10,473.0 10,493.0 5,792.7 5,807.4 C-4, 2T-28 9/11/1995 4.0 IPERF Zero° phasing; Oriented Zero°; 2 1/8" Enerjet 10,534.0 10,562.0 5,837.8 5,858.6 A-4, A-3, 2T-28 9/11/1995 4.0 IPERF Zero° phasing; Oriented Zero°; 2 1/8" Enerjet 10,590.0 10,608.0 5,879.4 5,892.8 A-2, 2T-28 9/11/1995 4.0 IPERF Zero° phasing; Oriented Zero°; 2 1/8" Enerjet 10,616.0 10,628.0 5,898.8 5,907.7 A-2, 2T-28 9/11/1995 4.0 IPERF Zero° phasing; Oriented Zero°; 2 1/8" Enerjet Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 10,300.9 5,666.1 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/13/1995 Notes: General & Safety End Date Annotation 8/20/2011 NOTE: WELDED 18" TALL, .375" CONDUCTOR EXTENSION IN PLACE 11/24/2010 NOTE: View Schematic w/ Alaska Schematic9.0 2T-28, 3/12/2020 8:07:56 PM Vertical schematic (actual) PRODUCTION; 38.4-10,883.9 IPERF; 10,616.0-10,628.0 IPERF; 10,590.0-10,608.0 IPERF; 10,534.0-10,562.0 IPERF; 10,473.0-10,493.0 SOS; 10,381.5 NIPPLE; 10,370.5 PACKER; 10,354.4 NIPPLE; 10,346.4 GAS LIFT; 10,300.9 SURFACE; 41.1-4,274.0 NIPPLE; 517.9 LEAK - SURFACE CASING; 336.0 CONDUCTOR; 40.5-121.0 HANGER; 37.0 KUP INJ KB-Grd (ft) Rig Release Date 8/31/1995 2T-28 ... TD Act Btm (ftKB) 10,890.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032022500 Wellbore Status INJ Max Angle & MD Incl (°) 67.64 MD (ftKB) 2,875.00 WELLNAME WELLBORE2T-28 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE MEMORANDUM State of Alaska Depth 5705 -Tubing 3000 IA Alaska Oil and Gas Conservation Commission TO: Jim Regg ,-j�Q1t DATE: Tuesday, June 22, 2021 7Il I Z Z ( P.I. Supervisor C ( � � SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. as per AIO 2B.066 2T-28 FROM: Brian Bixby KUPARUK RIV UNIT 2T-28 Petroleum Inspector Src: Inspector Reviewed By: pp P.I. Supry�F NON -CONFIDENTIAL Comm I Well Name KUPARUK RIV UNIT 2T-28 Insp Num: mitBDB210619062125 Rel Insp Num: API Well Number 50-103-20225-00-00 Inspector Name: Brian Bixby Permit Number: 195-092-0 Inspection Date: 6/18/2021 Well i 2T-28 PTD 1950920 Packer Type Ini W -TVD Type Test SPT' Test psi Depth 5705 -Tubing 3000 IA BBL Pumped: Interval 4 ,BBL Returned: REQVAR PIF 4 OA P Notes: 2 Year MITIA as per AIO 2B.066 Pretest Initial 15 Min 30 Min 45 Min 60 Min 2625 "� 2625. 2625 2615 1170 3410 - 3320 3310 70 70 - 70 70 Tuesday, June 22, 2021 Page 1 of 1 MEMORANDUM TO: Jim Regg P.1. Supervisor „ (� �! ZI �y FROM: Jeff Jones Petroleum Inspector Well Name KUPARUK RIV UNIT 2T-28 IInsp Num: mitJJ190725101416 Rel Insp Num: State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 25, 2019 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2T-28 KUPARUK RIV UNIT 2T-28 Ste: Inspector Reviewed By: :: P.I. Supry 79— NON -CONFIDENTIAL Comm API Well Number 50-103-20225-00-00 Inspector Name- Jeff Jones Permit Number: 195-092-0 Inspection Date: 6/22019 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1[ Type Inj TVD Tubing 2650 - 2650 2650 - 2650 PTD 1950920 " T) pe Test v'i Test psi ;0010 1A 1500 3300. 3210 -- ;210— — BBL Pumped: 34 BBL Returned: i OA 60 60 _ 60- 60 Interval) REQVAR P/F p- Notes: MIT -IA to max. anticipated injection press. Per A10 2B-066. I well inspected, no exceptions noted. Thursday, July 25, 2019 Page I of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Thursday,June 15,2017 Jim Regg P.I.Supervisor I CCR 606((7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-28 FROM: Lou Laubenstein KUPARUK RIV UNIT 2T-28 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2T-28API Well Number 50-103-20225-00-00 Inspector Name: Lou Laubenstein Permit Number: 195-092-0 Inspection Date: 6/5/2017 Insp Num: mitLOL170607153253 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2T-28 Type Inj W 'TVD 5705 ' Tubing 2610 ' 2610 2610 - 2610 PTD 1950920 Type Test SPT Test psi 3000 IA 1560 3400 3310 - 3290 , BBL Pumped: 3.2 ' BBL Returned: 3 ' OA 70 . 70 70 70 - Interval REQVAR P/F P Notes: MITIA per AIO 2B.066 to MA1P 20ThuSCONE° P 3, 320- Thursday, rsday,June 15,2017 Page 1 of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Friday,October 09,2015 P.I.Supervisor ' '�r'( f ON(i" SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-28 FROM: Jeff Jones KUPARUK RIV UNIT 2T-28 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2T-28API Well Number 50-103-20225-00-00 Inspector Name: Jeff Jones Permit Number: 195-092-0 Inspection Date: 9/25/2015 Insp Num: mitJJ150928083930 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min WeII'i 2T-28 - Type Inj I w 'TVD 5705 . Tubing 2400 2400 . 2400 2400 - PTD j 1950920 - Type Test SPT Test psi 3000 IA 1340 3300 - 3220 - 3220 - EQVAR Interval P/F �RP ✓ OA 1 70 - 70 70 70 J Notes: MITIA per AIO 213,066;3.5 BBLS diesel pumped, 1 well inspected,no exceptions noted. SCANNED='' . Friday,October 09,2015 Page 1 of 1 t 5-oc, 2.5%1M WELL LOG TRANSMITTAL DATA LOGGED 4 /t4/2015 M.K.BENDER To: Alaska Oil and Gas Conservation Comm. May 27, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 ;; E JUN 0 4 2G15 RE: Injection Profile : 2T-28 AOG CC Run Date: 5/24/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2T-28 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-103-20225-00 Injection Profile1 Color Log 50-103-20225-00 SCANNED JUL f ;015 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: *44416t Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. ,,"~~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Beverly Dian~than Lowell Is~ TO RE-SCAN Notes: ~5'~ "~ Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: Isl • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,October 02,2013 TO: Jim Regg l P.I.Supervisor I J 1017 (3 SUBJECT: Mechanical Integrity Tests 6 t CONOCOPHILLIPS ALASKA INC 2T-28 FROM: Chuck Scheve KUPARUK RIV UNIT 2T-28 Petroleum Inspector Src: Inspector Reviewed B P.I.Supry—i NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2T-28 A PI Well Number 50-103-20225-00-00 Inspector Name: Chuck Scheve Permit Number: 195-092-0 Inspection Date: 9/27/2013 Insp Num: mitCS130929071717 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min -- — ----- -- - - — -- 500 3220 3]90 _, ----- ---- --- Well 1950920 ,Type In sPT�'TVD 5905 - IA 3180 T 2T-28 YP J — --- Type Test, Test psi 3000 OA 60 58 - 59 60 - Inter - P REQVAR IP/F P Tubing 2650 -i 2625 -1 2650 -i 2625 - val _ Notes: Tested per AIO 2B.066 ,/ SCANNED '61- ' a Wednesday,October 02,2013 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,June 18,2013 TO: Jim Regg r) P.I.Supervisor r- " ' �/ " 24(( SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-28 FROM: Lou Grimaldi KUPARUK RIV UNIT 2T-28 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry , NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2T-28 API Well Number 50-103-20225-00-00 Inspector Name: Lou Grimaldi Permit Number: 195-092-0 Inspection Date: 6/1/2013 Insp Num: mitLG130601172132 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well' 2T-28 ' 'Type Inj W ',TVD 7 5705 " IA 746 3194 . 3113 3100 - PTD 1950920 Type Test. SPT Test psi 3000 . OA 68 69 69 69 Interval RE VAR .. P/F P J Tubing 2660 2640 2660 2675 Notes..AA compliance MIT required for variance.IA casing passed,Insufficient Tubing->1A differential,See subsequent test mitLG 130601173731 for passing results.Manifold pressure 2690 psi.Per J.Regg-test determined to be a Pass. J aa.0b4-- SCANNED FEB 2 0 2014 Page Tuesday,June 18,2013 g MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday,June 18,2013 TO: Jim Regg P.I.Supervisor k '7et q' f i 3 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-28 FROM: Lou Grimaldi KUPARUK RIV UNIT 2T-28 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry j 2_ NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2T-28 API Well Number 50-103-20225-00-00 Inspector Name: Lou Grimaldi Permit Number: 195-092-0 Inspection Date: 6/1/2013 Insp Num: mitLG130601173731 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 2T-28 Type lnj W TVD 5705 IA 3100 . 2015 2074 2079 Well . _ I 69 PTD 1950920 Type Test SPT Test psi 3000 . OA 2675 2695 2680..._1 2620 r � Interval : Q VAR P P/F - !Tubing Notes: AA compliance Test to exhibit>500 psi DP tubing->1A.See days prior MIT"mitLG130601 172132"for Casing/Packer pressure test. CDropped IA pressure 1085 psi and observe for 30 minutes. , rte, Z,°> t �: SCANNED FEB 2 0 2014 • Tuesday,June 18,2013 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaaI alaska.gov; AOGCC.Inspectorsealaska.aov; phoebe.brooksaalaska.aov chris.wallaceaalaska.gov OPERATOR: ConocoPhillips Alaska,Inc FIELD/UNIT/PAD: Kuparuk/KRU/2T Pad ,, q(z-I i?, DATE: 06/01/13 a5-- 0 OPERATOR REP: Freeborn/Hight/Phillips 11 1 ^ AOGCC REP: Lou Grimaldi -1.-"-- �,() Packer Depth _ Pretest Initial 15 Min. 30 Min. 45 Min._ 60 Min. �! Well 2T-15 Type Inj. W TVD 5,437' Tubing 2,650 2,650 2,650 2,660 Interval 4' P.T.D. 1860450 Type test P Test psi 1500 Casing 666 2,002 1,934_ 1,913 P/F P Notes: OA 80 80 90 90 Well 2T-18 Type Inj. W TVD 5,759' Tubing 2,650 2,650 2,640 2,640 Interval 4 P.T.D. 1950170 Type test P Test psi 1500 Casing 1,044 2,000 1,971 1,962 P/F P Notes: OA 740 840 850 850 Well 2T-26 Type inj._ W TVD 5,715' Tubing 2,600 2,600 2,620 2,620 Interval 4 P.T.D. 1950820 Type test P Test psi 1500 Casing 1,240, 2,010 1,991. 1,994 P/F • P Notes: OA 530 605 605 605 Well 2T-28 Type Inj. W TVD 5,706' Tubing 2,660 2,640 2,660 2,675 Interval V / P.T.D..1950920 Type test P Test psi 3000 Casing 746 3,194 3,113 3,100 P/F P (/� Notes:A102B.66 MITIA to Max anticpated injection Press OA 68 69 69 69 Well 2T-28 Type Inj. W TVD 5,706' Tubing 2,675_ 2,675 2,680 2,620 Interval. P.T.D. 1950920 Type test M Test psi_ 3,000' Casing 3,100 2,015 2,074 2,079 P/F p Notes: OA 69 69 69 69 AOGCC Inspector requested second test Well 2T-32 Type Inj. W TVD 5,731' Tubing 2,900 2,900 2,900 2,900 Interval 4 P.T.D. 1950490 Type test P Test psi 1500 Casing 1,170 1,950 1,910 1,900 P/F P Notes: Non-witnessed test OA 200 200 200 200 AOGCC Inspector left location prior to test Well 2T-36 Type Inj. W TVD 5,767' Tubing 1,150 1,150 1,150 1,150 Interval 4 P.T.D. 1951020 Type test P Test psi 1500 Casing 610 2,000 1,940 1,931 P/F P Notes: OA 410 500 490 490 Wel1.2T-201 Type Inj. W - TVD 2,762' Tubing 900 - 900 900 900 ' Interval 4 P.T.D. 1951220 ' Type test P - Test psi 1500 Casing 957 '3,000 '2,986 '2,986 P/F P Notes: Non-witnessed test OA 180 • 180 180 180 • AOGCC Inspector left location prior to test Well 2T-217A Type Inj. W TVD 3,006' Tubing 1,170 1,170 1,170 1,170 I Interval 4 P.T.D. 2000740 _ Type test P Test psi 1500 Casing 280 2,000 1,940 1,920 I P/F P Notes: Non-witnessed test OA AOGCC Inspector left location prior to test TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test FEB 2 0 201 SCANNED Form 10-426(Revised 11/2012) MIT KRU 2T 4 year 6-01-13Revised.xls • • Nov ConocoPhillips RECEIVED Alaska L) C T 0 9 2012 P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 AOGCC October 5, 2012 Commissioner Dan Seamount Alaska Oil & Gas Commission 19 t 5` 0(12-- 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 c9:1- Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped in the summer /fall of 2012. The corrosion inhibitor /sealant was pumped in the month of September 2012.The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, /74 4 Martin Walters ConocoPhillips Well Integrity Projects Supervisor ! • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 10/05/2012 1D,WSW,1F,2F,2L,2T,2Z,3G,31 & 3M PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft _ gal 1D-113 50029229170000 1981780 2" n/a 8" n/a 5.1 9/27/2012 1D-117 50029228440000 1972370 T 0.80 25" 7/22/2012 8.7 9/27/2012 WSW -11 50029208820000 1822120 SF n/a 8" n/a 2.9 9/30/2012 1F-11 50029209930000 1831150 19'8" 3.40 12" 7/22/2012 3.4 9/27/2012 2F -19 50029227280000 1962010 7'5" 1.30 18" 9/19/2012 19 9/27/2012 2L -305 50103202790000 1982400 SF n/a 7" n/a 4.4 9/28/2012 2T -28 50103202250000 1950920 9" n/a 27" n/a 13.6 9/27/2012 2Z -10 50029213780000 1851370 5'9" 0.80 23" 9/19/2012 7.7 9/30/2012 3G -03 50103202450000 1961220 2" n/a 12" n/a 7.5 9/28/2012 31 -06 50029219350000 1890380 7' 0.80 11" 7/22/2012 6 9/28/2012 3M -13 50029217200000 1870400 7'7" 0.50 12" 7/22/2012 4.7 9/28/2012 • ' ® Conoco Ai lips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 _ _ ; MAR 2 0, AWL March 9, 2012 k\J Commissioner Dan Seamount Alaska Oil at Gas Commission 333 West 7 Avenue, Suite 100 -- Anchorage, AK 99501 q6" 07g_ Commissioner Dan Seamount Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells were found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped in the fall of 2011. The corrosion inhibitor/sealant was pumped on various days in January and February 2012. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907-659-7043, if you have any questions. Sinc7, MJiveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 3-09 -2012 2A,M,T,X PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft pal 2A-19A 50103201970100 2010830 12" NA 39" NA 15.3 2/11/2012 2M-02 50103201790000 1920830 10'5" 1.62 19" 11/22/11 5.1 2/11/2012 2M-29 50103201830000 1920970 SF NA 24" NA 3.4 2/11/2012 2T-18 50103202130000 1950170 4'2" 0.50 9" 11/22/11 2.55 2/12/2012 2T-28 50103202250000 1950920. 9" NA 16" NA 2T-207 50103202780000 1982310 22'3" 3.70 7" 11/21/11 2.98 2/12/2012 2T-215 50103202800000 1982420 18'6" - 2.40 10" 11/22/11 4.25 2/12/2012 2X-06 50029209880000 1831100 SF NA . 21" NA 2.13 2/12/2012 • i 2 -( - 37 � WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. December 20, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 4 M A {'! 4 'O12 RE: Injection Profile: 2T-28 Run Date: 12/3/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2T -28 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50- 103 - 20225 -00 Injection Profile Log 1 Color Log 50 -103- 20225 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: �`� � Signed: J • Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Tuesday, December 06, 2011 3:38 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: Monthly failed MIT report for November 2011 Attachments: CPAI Failed MITIA Monthly Data 11- 11.zip Tom, Jim, Guy Attached is the monthly failed MIT report for November 2011. 1 Q -02B was deleted (after a patch was set across CMU, witnessed MITIA performed and 10 -404 were submitted in October). 2T -28 and 3K -30 were added 1 -4 1 tSS -c7 1Q-11 was inadvertently deleted from October's report after it had its AA cancelled. It has been added back into November's report and will remain on future reports. Thanks }f i t a , i Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 12/7/2011 • • ConocoPhillips Well 2T -28 Injection Data ♦ Water Injection 0 Gas Injection 4000 3500 3000 .N 2500 / • � a 2000 A " 1500 1000 - 500 - I 0 0 500 1000 1500 2000 2500 3000 3500 Injection Rate, bwpd or mscfpd Date of Water Gas Tubing IA Pressure OA Pressure Injected Injected Pressure Injection (bwpd) (mscfpd) (psi) (psi) (psi) 30- Nov -11 1480 0 2089 450 50 29- Nov -11 1427 0 2063 450 50 28- Nov -11 1455 0 2096 450 50 27- Nov -11 1544 0 2155 500 50 26- Nov -11 1555 0 2156 500 50 25- Nov -11 1382 0 2066 400 5 24- Nov -11 1469 0 2128 400 5 23- Nov -11 1827 0 2324 550 5 22- Nov -11 2351 0 2571 550 5 21- Nov -11 2348 0 2564 600 10 20- Nov -11 2350 0 2564 600 10 19- Nov -11 2344 0 2562 600 10 18- Nov -11 2308 0 2566 600 10 17- Nov -11 2343 0 2579 600 10 16- Nov -11 2317 0 2581 600 10 15- Nov -11 2377 0 2599 600 10 14- Nov -11 2345 0 2590 600 10 13- Nov -11 2427 0 2594 600 10 12- Nov -11 2743 0 2592 600 10 11- Nov -11 2727 0 2572 500 10 10- Nov -11 2609 0 2554 600 10 9- Nov -11 2773 0 2593 500 10 8- Nov -11 2700 0 2570 500 10 7- Nov -11 2713 0 2581 500 10 6- Nov -11 2889 0 2598 500 10 5- Nov -11 2747 0 2571 550 10 4- Nov -11 2743 0 2573 550 10 • • ConocoPhillips Well 2T -28 Injection Data • Tbg Psi IA Psi • OA Psi I 4000 3500 3000 - C1 ".........•••••••" y • 2500 • a 2000 ~.. E 1500 - 1000" 500 '" 0 08/11 09/11 10/11 11/11 12/11 Date PTD 195 -092 AIO 2B.066 Issued 10/26/2011 OA x Formation communication 10/2/11 - Witnessed MITIA passed 10/17/11 - Submitted AA application 10/26/11 - Received approved AA AIO 2B.062 requires any pressure bleeds to be reported monthly No pressure bleeds have occurred within the last month • ��` JqZ OT ALASKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 ADMINISTRATIVE APPROVAL AREA INJECTION ORDER 2B.066 Ms. M. J. Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. R . , P.O. Box 100360 " `' Anchorage, AK 99510 -0360 RE: KRU 2T -28 (PTD 1950920) Request for Administrative Approval Kuparuk River Oil Pool Dear Ms. Loveland: In accordance with Rule 9 of Area Injection Order ( "AIO ") 02B.000, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS ConocoPhillips Alaska Inc. (CPAI) request for administrative approval to continue water injection in the subject well. Kuparuk River Unit (KRU) 2T -28 exhibits a subsidence related surface casing leak at about 336' below pad surface. The AOGCC finds that CPAI does not intend to perform repairs at this time, deferring until a rig workover can be justified. Reported results of CPAI's diagnostic procedures and wellhead pressure trend plots indicate that KRU 2T -28 exhibits at least two competent barriers to the release of well pressure. AOGCC's administrative approval to continue WATER INJECTION ONLY in KRU 2T -28 is conditioned upon the following: 1. CPAI shall record wellhead pressures and injection rate daily; 2. CPAI shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli; 3. CPAI shall perform an MITIA every 2 years to the maximum anticipated injection pressure; 4. IA pressure not to exceed 2000 psi. 5. OA pressure not to exceed 300 psi. 6. CPAI shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; AIO 2B.066 • • October 26, 2011 Page 2 of 2 7. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 8. The MIT anniversary date is October 2, 2011. DONE at Anchorage, Alaska and dated • ctob - 26, 2011. Daniel T. amount, Jr. J1.;.,- o man Cathy . Foerster Chair, Commissioner Commissioner Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[t]he questions reviewed on appeal are limited to the questions presented to the AOGCC by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. • • ConocoPhillips ;..., Alaska f 7$1 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Gals. Co r: L, of October 16, 2011 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. presents the attached proposal per AIO 2B, Rule 9, to apply for Administrative Approval allowing well 2T -28 (PTD 195 -092) to be online in water only injection service with a known surface casing leak. ConocoPhillips intends to pursue repairs should MI injection be desired in the future. If a successful repair is achieved we will request the well be returned to normal status and resume the ability to inject MI. If you need additional information, please contact myself or Martin Walters at 659 -7043, or Brent Rogers / Kelly Lyons at 659 -7224. Sincerely, MJ L. eland Well Integrity Supervisor ConocoPhillips Alaska Inc. Enclosures • • ConocoPhillips Alaska, Inc. Kuparuk Well 2T -28 (PTD# 195 -092) Technical Justification for Administrative Relief Request Purpose ConocoPhillips Alaska, Inc. proposes that the AOGCC approve this Administrative Relief as per request Area Injection Order 2B, Rule 9, to continue water only injection with a known q p J surface casing leak for Kuparuk injection well 2T -28. Well History and Status Kuparuk River Unit well 2T -28 (PTD# 195 -092) was drilled and completed in 1995 as a service well. It was reported to the Commission on 09/23/11 with a suspected subsidence related surface casing leak. Diagnostics were conducted which verified the surface casing to formation leak with an estimated depth of approximately 336' below the surface (conductor shoe is at 121' RKB). The following pertinent operations to show tubing and production casing integrity have been completed to date: Date Operation Result Comment 10/02/11 MITIA Passed Witnessed by Lou Grimaldi 08/25/11 MITIA Passed 10/07/10 Gyro Survey NA 06/01/09 MITIA Passed Witnessed by Jeff Jones 06/02/07 MITIA Passed Witnessed by Jeff Jones Considering that the leak is too deep to access via excavation, the well will require a workover or an alternate repair technology to remediate. ConocoPhillips requests administrative approval to continue water only injection until the well can be repaired. Well Integrity Supervisor 10/16/2011 • • Barrier and Hazard Evaluation Tubing: The 3 -1/2 ", 9.3 ppf, L -80 tubing has integrity to the packer @ 10354' RKB based upon the passing MITIAs as outlined above. Production casing: The 7 ", 26 ppf, L -80 production casing set at 10877' RKB has an internal yield rating of 7240 psi and has integrity to the packer @ 10877' MD based upon a passing MITIAs as outlined above. Surface casing: The 9 -5/8 ", 40 ppf, L -80 surface casing set at 4274' RKB has an internal yield pressure rating of 5750 psi but does not have integrity based upon surface casing leak diagnostics. Primary barrier: The primary barrier to prevent a release from the well and provide zonal isolation is the tubing and packer. Second barrier: The production casing is the secondary barrier should the tubing fail. Monitoring: Each well is monitored daily for wellhead pressure changes. Any deviations from approved MAOP annular pressures require investigation and corrective action, up to and including a shut -in of the well. T /IO plots are compiled, reviewed, and submitted to the AOGCC for review on a monthly basis. Proposed Operating and Monitoring Plan 1. Well will be used for water injection only (no gas or MI allowed). 2. Perform a passing MITIA every 2 years to the maximum anticipated injection pressure. 3. IA pressure not to exceed 2000 psi (28% internal yield). 4. OA pressure will be maintained as low as reasonably possible not to exceed 300 psi 5. Submit monthly reports of daily tubing & IA pressures, injection volumes, and any pressure bleeds on any annuli. 6. Shut -in the well should MIT's or injection rates and pressures indicate further problems with appropriate notification to the AOGCC. 7. Workover and/or repair the well prior to gas injection consideration with appropriate AOGCC notification Well Integrity Supervisor 10/16/2011 2 • . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaa(Thalaska.Qov; doa .aoacc.prudhoe.bay(a)alaska.aov; phoebe.brooksetalaska.aov; tom.maunderbalaska.00v OPERATOR: ConocoPhillips Alaska Inc. FIELD / UNIT / PAD: Kuparuk / KRU / 2T DATE: 10/02/11 OPERATOR REP: Ives /Bybee /Jensen AOGCC REP: Lou Grimaldi Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2T -28 Type Inj. W TVD 5,660' Tubing 2,525 2,500 2,475 2,500 Interval 0 P.T.D. 1950920 _ Type test P Test psi_ 1500 Casing 605 3,200 3,158 3,141 PIF P Notes: OA 104 106 106_ 107 Test for AA application Wet Type Inj. TVD Tubing Interval P.T.D. Type test Test psi_ Casing PIF Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test_ Test psi_ Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi_ Casing PIF Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10-426 (Revised 06/2010) MIT KRU 2T - 28 10 - 11.xis „.. UP 2T -28 Conoco Phillips Well Attribu Max Angle TD Alaska, Ir?; - ° - Wel!bore ApwWI Field Name Well Status Inc/ (°) MD MKS) Act Btnl (RKB) w, 501032022500 KUPARUK RIVER UNIT INJ 67.64 2,875.00 10,890.0 Comment H25 (ppm) Date Annotation End Data KB - 43rd (ft) Rig Release Date "' _ SSSV: NIPPLE Last WO: 8/31/1995 Well Conng. - 27.28 10/6/2011 10.54 W AM _ - Schematic - Actual Annotation Depth (RKB) End Date Annotation Last Mod ... End Date Last Tag: 10,614.0 12/14/2008 Rev Reason: FORMAT UPDATE ninam 10/6/2011 Casing Strings -- -- Casing Description string 0... String ID ... Top (RKB) Set Depth (t... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 42.0 121.0 121.0 62.58 H WELDED Casing Descripbon String 0... String ID ... Top (RKB) Set Depth (t... Set Depth )TVD) String Wt.. String ... String Top Thrd RANGER. 37 - SURFACE 95/8 8.835 41.1 4,274.0 2,891.7 40.00 L BTC Casing Description String 0... String ID ... Top (RKB) Set Depth (t... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 31.8 10,877.3 6,095.5 26.00 L-80 BTC -MOD . Tubing Strings 1 Tubing Description String 0... String ID ... Top (6 (9) Set Depth (r... Set Depth (TVD) ... String Wt.-. String ... String Top Thrd TUBING 3 1/2 2.992 37.0 10,382.4 5,726.0 9.30 L -80 ABM -EUE Completion Details k Top Depth (TVD) Top Inc! Noml... Top (RKB) (RKB) ( °) Item Description Comment ID (In) 37.0 37.0 - 0.13 HANGER FMC GEN IV TUBING HANGER 3.500 CONDUCTOR, j I 42.121 517.9 517.7 3.32 NIPPLE CAMCO DS LANDING NIPPLE NO GO 2.812 10,346.4 5,699.5 42.70 NIPPLE CAMCO W -1 SELECTIVE LANDING NIPPLE 2.812 10,354.4 5,705.5 42.69 PACKER BAKER SAB-3 PACKER w/ K -22 ANCHOR SEAL ASSEMBLY 3.250 10,370.5 5,717.3 42.67 NIPPLE CAMCO D NIPPLE NO GO 2.750 NIPPLE, 518 a 10,381.5 5,725.4 42.66 SOS BAKER SHEAR OUT SUB 2.992 Perforations & Slots Shot - Top (TVD) Btm (TVD) Dens Top MKS) Btm (RKB) (RKB) (RKB) Zone Date ).h... Type Comment 10,473 10,493 5,789.7 5,804.8 C-4, 2T -28 9/11/1995 4.0 IPERF Zero deg. phasing; Oriented Zero i deg.; 2 1/8" Enerjet 10,534 10,562 5,835.8 5,857.0 A -4, A -3, 2T -28 9/11/1995 4.0 IPERF Zero deg. phasing; Oriented Zero • deg.; 2 1/8" Enerjet 10,590 10,608 5,878.2 5,891.8 A -2, 2T -28 9/11/1995 4.0 IPERF Zero deg. phasing; Oriented Zero deg.; 21/8" Enerjet SURFACE J 10,616 10,628 5,897.9 5,906.9 A -2, 2T -28 9/11/1995 4.0 IPERF Zero deg. phasing; Oriented Zero 414 214 - -_- deg.; 2 1/8" Enerjet (1 Notes: General & Safety End Date Annotation 11/24/2010 NOTE: View Schematic w/ Alaska Schematic9.0 8/20/2011 NOTE: WELDED 18" TALL, .375" CONDUCTOR EXTENSION IN PLACE GAS LIFT 10 NIPPLE 10 346 11! 11 PAC _ 1 0.3 5 4 � NIPPLE, 10,370 1 SOS, 10.381 1 _...1 IPERF 493 10. 10. 493 IPERF, 10,534 - 10,562 ll 0.590 IPERF, 6600 . Mandrel Details Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (RKB) MB) (°) Make Model (!n) Sery Type Type )in) (PO Run Date Com... ■ 1 10,300.9 5,666.1 42.75 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/13/1995 IPERF 10.616- 10.628 PRODUCTION, 32- 10,877 -\ ' TD, 10,890 • • Brooks, Phoebe L (DOA) FTD' 1950q From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Thursday, October 06, 2011 2:38 PM To: Brooks, Phoebe L (DOA) Cc: Worthy, Michael S (Northland Staffing Services); Gates, Matthew P; Miller, Nina (Northlan: Staffing Services) Subject: RE: MIT on 3Q -05 and 2T -28 attached Attachments: 2T-28.pdf Phoebe, - Thanks. We also got the 2T -28 well schematic revised now to reflect the Packer set depth at 5705' TVD (see attached). Regards, John Peirce Problem Wells Supv (907)- 659 -7224 office From: Brooks, Phoebe L (DOA) [ mailto :phoebe.brooks @alaska.gov] Sent: Thursday, October 06, 2011 8:08 AM To: NSK Problem Well Supv Cc: Regg, James B (DOA) Subject: RE: MIT on 3Q -05 and 2T -28 attached John, I've attached a revised report reflecting a Packer TVD of 5705'. tz ^i ■ (; it Please let me know if you disagree. Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907 - 793 -1242 Fax: 907 -276 -7542 From: NSK Problem Well Supv [ mailto :n1617 @conocophillips.com] Sent: Wednesday, October 05, 2011 4:26 PM To: Brooks, Phoebe L (DOA) Cc: Gates, Matthew P; Worthy, Michael S (Northland Staffing Services) Subject: RE: MIT on 3Q -05 and 2T -28 attached Phoebe, Looking at our Directional Survey database data table for 2T -28, I see we have 5665.45' TVD at 10300' MD, and the next deeper shot point on the survey is 5780.75' TVD at 10456.80' MD. Based on that, I would say your database showing 5705' TVD at 10354' MD looks to be correct. I don't know how we show 5660.2' TVD for the 10354' MD Packer depth on the 2T -28 well schematic, as that doesn't fit properly with our Directional Survey data. I'll have to cc our Wellview Techs to see if we can get an answer why we're seeing the TVD reported for the Packer as it is on our 2T -28 well schematic. 1 • Regards, John Peirce Problem Wells Supv (907)- 659 -7224 office From: Brooks, Phoebe L (DOA) [mailto:phoebe.brooks @alaska.gov] Sent: Wednesday, October 05, 2011 10:02 AM To: NSK Problem Well Supv Subject: RE: MIT on 3Q -05 and 2T -28 attached John, Will you please verify the Packer TVD for 2T- 28...the figure listed was 5660' however, we have 5705' (MD of 10354') in our database. Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907 -793 -1242 Fax: 907 - 276 -7542 From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Tuesday, October 04, 2011 3:45 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Subject: MIT on 3Q -05 and 2T -28 attached All, Please see attached MIT Forms for 3Q -05 and 2T -28 performed on 10- 02 -11: John Peirce NSK Problem Wells Problem Well Supervisor (907)- 659 -7224 office 2 „� Al UP 2T -28 COnOCOP dairy 1 Well At Max Angle TD Alaska. If1C. Wellbore API/DWI Field Name Well Status Intl ( °) MD (ftKB) Act Btm (MB) ,,rxY. „ 501032022500 KUPARUK RIVER UNIT INJ 67.64 2,875.00 10,890.0 Comment N2S (ppm) Date Annotation End Date KBGrd (ft) Rig Release Date °°° con wen 2T-25,10/5/2011 10:54:04 AM SSSV: NIPPLE Last WO: 8/31 /1995 SchematIc - Actual Annotation Depth (f1KB) End Date Annotation Last Mod ... End Date Last Tag: 10,614.0 12/14/2008 Rev Reason: FORMAT UPDATE ninam 10/6/2011 Casing Strings 1 ; � Casing Description String 0... String ID ... Top (11KB) Set Depth (f... Set Depth ((VD)... String Wt.. String ... String Top Thrd CONDUCTOR 16 15.062 42.0 121.0 121.0 62.58 H WELDED Casing Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt.. String ... String Top Thrd HANGER, 37 SURFACE 95/8 8.835 41.1 4,274.0 2,891.7 40.00 L BTC Casing Description String 0 ... String ID ... Top (ftKB) Set Depth (f._ Set Depth (TVD) ... String Wt.. String ... String Top Thrd 7•1 PRODUCTION ■ 7 ; 6.276 31.8 10,877.3 6,095.5 26.00 L-80 BTC -MOD Tubing Strings Tubing Description String 0... String ID . Top (ftKB) Set Depth (f... Set Depth (ND) !String Wt.. String ... String g Top Thrd TUBING 3 1/2 i 2.992 37.0 10,382.4 5,726.0 I 9.30 L-80 I ABM -EUE Completion Details Top Depth (TVD) Top Ind hoed... Top (MB) MB/ (°) Item Description Comment ID (In) 37.0 37.0 - 0.13 HANGER FMC GEN IV TUBING HANGER 3.500 CONDUCTOR, 42 - 121 517.9 517.7 3.32 NIPPLE CAMCO DS LANDING NIPPLE NO GO 2.812 l:: 10,346.4 5,699.5 42.70 NIPPLE CAMCO W -1 SELECTIVE LANDING NIPPLE 2.812 I 10,354.4 5,705.5 42.69 PACKER BAKER SAB-3 PACKER w/ K -22 ANCHOR SEAL ASSEMBLY 3.250 10,370.5 5,717.3 42.67 NIPPLE CAMCO 0 NIPPLE NO GO 2.750 NIPPLE, 518 -- it 10,381.5 5,725.4 42.66 SOS BAKER SHEAR OUT SUB 2.992 Perforations & Slots Shot Top (1VD) Wm (ND) Dens Top Ifn(B) Wm (ftKB) OLKBI MB) Zone Date (sh - -. Type Comment 10,473 10,493 5,789.7 5,804.8 C4, 2T -28 9/11/1995 4.0 IPERF Zero deg. phasing; Oriented Zero deg.; 2 1/8” Enerjet 10,534 10,562 5,835.8 5,857.0 A-4, A-3, 2T -28 9/11/1995 4.0 IPERF Zero deg. phasing; Oriented Zero deg.; 2 1/8” Enerjet 10,590 10,608 5,878.2 5,891.8 A -2, 2T -28 9/11/1995 4.0 IPERF Zero deg. phasing; Oriented Zero deg.; 2 1/8" Enerjet SURFA 10,616 10,628 5,897.9 5,906.9 A -2, 2T -28 9/11/1995 4.0 IPERF Zero deg. phasing; Oriented Zero 4 • ' deg.; 2 1/8" Enerjet Notes: General & Safety End Date Annotation 11/24/2010 NOTE: View Schematic w/ Alaska Schematic9.0 GAS LIFT, 8/20/2011 NOTE: WELDED 18" TALL, .375" CONDUCTOR EXTENSION IN PLACE 10,301 I I NIPPLE, 10,348 i Jy(`` ! 1 PACKER. _... _. — 10,354 s NIPPLE. 10,370 SOS, 10,381 III IPERF_ • , 10,473- 10,483 IPERF, . t0, 1 1 IPERF, _ pg. Top Depth Top Port (ND) Intl OD Valve Latch Size TRO Run Stir Top ((KB) (16(B) r) Make Model On) Saw Type Type On) (pe0 Run Date Cyan... 1 10,300.9 5,666.1 42.75 CAMCO MMM 1 12 GAS LIFT DMY RK 0.000 0.0 9/13/1995 IPERF, . 10,811510,828 PRODUCTION, 32-10,877 � TD, 10, • . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, October 04, 2011 TO: Jim Regg ' ' ()Ili i P.I. Supervisor 1 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T -28 FROM: Lou Grimaldi KUPARUK RIV UNIT 2T -28 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 2T - 28 API Well Number: 50 - 103 - 20225 - 00 - 00 Inspector Name: Lou Grimaldi Insp Num: mitLG1 1 1 002094303 Permit Number: 195 - 092 - Inspection Date: 10/2/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2T -28- Type Inj. I W - TVD 5705 - IA 605 3200 , 3158 3141 - P.T.D 1950920' TypeTest S Test psi 1500 - OA 104 106 106 107 • Interval OTHER P/F P Tubing 2525 2500 2475 2500 Notes: Test is for upcoming AA application for Surf casing leak. 4.6Bbl pumped, 4.5 returned. Good test. - Tuesday, October 04, 2011 Page 1 of 1 • • Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Saturday, September 24, 2011 8:50 AM To: 'NSK Well Integrity Proj'; Schwartz, Guy L (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv Subject: RE: 2T -28 (PTD 195 -092) MJ, Keep us informed regarding the diagnostics. Tom Maunder, PE AOGCC From: NSK Well Integrity Proj [ mailto :N1878 @conocophillips.com] Sent: Friday, September 23, 2011 5:36 PM To: Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: 2T -28 (PTD 195 -092) Tom, Injection well 2T -28 is suspected to have surface casing leak approximately 330' below the surface due to subsidence. ConocoPhillips intends to leave the well online to complete diagnostic testing to confirm barriers for an AA application. Please let us know if this plan is not acceptable. MJ Loveland / Martin Walters Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659 -7043 MJ's CeII (907) 943 -1687 9/24/2011 • • ConocoPhillips Alaska CIV P.O. BOX 100360 AUG 2 3 2011 ANCHORAGE, ALASKA 99510 -0360 Alaska QH & Gas Cep. Commission Anchora$e August 20, 2011 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Ej ' : �; t�1k AUG VOluow Commissioner Seamount: Enclosed please find the 10 -404 Report of Sundry Operations for ConocoPhillips Alaska, Inc., well 2T -28, PTD 195 -092, Sundry 311 -165 conductor extension. Please call MJ Loveland or Martin Walters at 659 -7043 if you have any questions. Sincerely, C oveland ConocoPhillips Well Integrity Projects Supervisor ICI STATE OF ALASKA Ai 4 OAS KA OIL AND GAS CONSERVATION CliRMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon fl Repairwell r j Plug Perforations fJ Stimulate f Other roi conductor extension Alter Casing [ Pull Tubing fl Perforate New Pool El Waiver [1 Time Extension Ci Change Approved Program if Operat. Shutdow n c Perforate n Re -enter Suspended Well f 2. Operator lope: • " 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development El Exploratory r 195 - 092 3. Address: 6. API Number: 0 A, chora e Alas 99510 Stratigraphic fl Service 00 ,, � 9 �I P. O. Box 100360, 50- 103 - 20225 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025548''— 2T - 9. Field /Pool(s): ,,,,,, Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 10890 feet Plugs (measured) None true vertical 6105 feet Junk (measured) None Effective Depth measured 10794 feet Packer (measured) 10354 true vertical 5986 feet (true vertucal) 5705 Casing Length Size MD TVD Burst Collapse CONDUCTOR (Q 80 16 121 121 0 0 SURFACE (QC) 4233 12 4274 2882 0 0 PRODUCTION 10846 7 10877 6049 0 0 CONDUCTOR 18" 16 NA 0 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 10473 - 10493, 10534 - 10562, 10590 - 10608, 10616 -10628 True Vertical Depth: 5743 -5758, 5789 -5810, 5832 -5845, 5851 -5860 Tubing (size, grade, MD, and TVD) 3.5, L - 80, 10381 MD, 5725 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER SAB -3 @ 10354 MD and 5705 TVD NIPPLE - Type Not Found (Manual Entry Required) @ 0 MD and 0 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 14. Well Class after work: Copies of Logs and Surveys run NA Exploratory r Development fl Service gri, Stratigraphic r; 15. Well Status after work: on fl Gas fl WDSPL f i Daily Report of Well Operations GSTOR c WINJ y c WAG GINJ c SUSP c SPLUG c 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt 311 -165 Contact MJ Loveland/ artin W- ers Printed Name MJ Lovela ,%` Title — WI Proj Supervisor 6:/ cy /7/2/ 1 Signature one: 659-7043 Date • Form -404 Revised 10/2 eC MS AUG 2 7 2 3 .4 ' Submit Original Only Sri, F iri t s ' 10. = hillips Alaska, In -1 I • OConocoP This photo is copyright by ..,n •' " � - Conoco Ph Hips Alaska, Inc. and cannot be released or published without express written consent of ConocoPhillips Alaska -Ella R `,.e 1,1 1 ' tu^ r r 4 • 2T -28 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 08114/11 Welded 18" tall 16 "x62.58 #x.375" conductor extension in place. • • sinE uf A[mA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 MJ Loveland Well Integrity Project Supervisor - i '16 te- ConocoPhillips Alaska, Inc. -k ` - 0 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2T -28 Sundry Number: 311 -165 Dear Ms. Loveland: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this / 1 day of May, 2011. Encl. STATE OF ALASKA (J)`)4 0� ti ALASK L AND GAS CONSERVATION COMMISSI� �L ,� �1 ! �/ y APPLICATION FOR SUNDRY APPROVALS S� 20 AAC 25.280 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Plug Perforations r Perforate r Rill Tubing r Time Extension r Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing r Other:conductor extension r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 195 -092 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20225 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No r 2T - 28 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL0025548 ' Kuparuk River Field / Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10890 • 6105 • 10794' 5986' Casing Length Size MD TVD Burst Collapse CONDUCTOR (QC) 80 16 121' 121' SURFACE (QC) 4233 12 4274' 2882' PRODUCTION 10846 7 10877' 6049' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10473 - 10493, 10534 - 10562, 10590- 10608, 10616 -10628 5743 -5758, 5789 -5810, 5832 -5845, 5851 -5860 3.5 L - 10381 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER SAB -3 MD= 10354 TVD= 5705 NIPPLE - no SSSV MD= TVD= none 12. Attachments: Description Summary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/15/2011 Oil r Gas r WDSPL r Suspended r 16. Verbal Approval: Date: VVINJ r GINJ r WAG r/ . Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct t e best of my knowledge. Contact: MJ Loveland /Perry Klein Printed Name MJ Lovel Title: WI Proj Supervisor / Signature Phone: 659 7043 Date p ,; ` Commission Use Only / ` Sundry Number: 31 1 — t ( 0 6 Conditions of approval: Notify Commission so that a representative may witness RECEIVED' 1 1 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r �p�O ,o Y q 1! Other: --- P/z 16 alde-4.is■••�h: 4 - S / / ro r� ' Alaska Oil & ri Ca; s,. Commission Subsequent Form Required: /� _ L./ t� r Lt )ertigfi M.,„, APPROVED BY S /'/ J / Approved by r COMMISSIONER THE COMMISSION Date: 11 A ,, . . c � Submif n Duplicate Form 10 -403 Revi M�� 201 : r , ` + . IGINAL / ' �/G // / / "4 3-4/44/ • • ConocoPhillips Alaska, Inc. Kuparuk Well 2T -28 (PTD 195 -092) SUNDRY NOTICE 10 -403 APPROVAL REQUEST May 9, 2011 This application for Sundry approval for Kuparuk well 2T -28 is to extend the conductor to original height so as to prevent any further corrosion to SC. This well is Kuparuk injection well and is currently on line. At some point during normal operations the conductor subsided about 18 inches. With approval, the conductor extension will require the following general steps: 1. Remove landing ring from conductor. 2. Examine SC below where landing ring was for any corrosion damage. 3. Install anti - corrosion coating on SC as specified by CPAI Corrosion Engineer. 4. Extend the conductor to braiden head and fill the void with cement and top off with sealant. 5. File 10 -404 with the AOGCC post repair. NSK Problem Well Supervisor 05/07/05 MEMORANDUM TO: Jim Regg ~~~~t lJ~(~~~~ P.I. Supervisor FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 10, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-28 KIJPARUK RIV UNIT 2T-28 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv 'L1 D,~ Comm Well Name: KUPARUK RIV UNIT 2T-28 Insp Num: mitJJ090608125402 Rel Insp Num: API Well Number: 50-103-20225-00-00 Permit Number: 195-092-0 / Inspector Name: Jeff Jones Inspection Date: 6/1/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We^ ~ 2T-2S Type Inj. W TVD 5660 ~~IA -ti- 750 ~ P.T.D 1950920 TypeTest sPT Test psi 1500 ~ QA I 0 2000 ' 1930 1930 _ 60 80 80 Interval a~rRTST P/F P '~ Tubing 2~so_ 2soo 2soo 2soo Notes: 2.8 BBLS diesel pumped, 1 well inspected; no exceptions noted. •, t ~ [' ~, i_~~ 3 ~„ , y Wednesday, June 10, 2009 Page I of 1 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg ~ P.I. Supervisor ··'1 ef1 b/-t/D7 DATE: Wednesday, June 06, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA lNC FROM: Chuck Scheve Petroleum Inspector 2T-28 KUPARUK RIV UNIT 2T·28 \qG~Dq~ Reviewed By: P.I. Suprv-JB/2.- Comm Src: Inspector NON-CONFIDENTIAL Well Name: KUP ARUK RIV UNIT 2T -28 API Well Number: 50-103-20225-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS070603 145207 Permit Number: 195-092-0 Inspection Date: 6/2/2007 / Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 2T-28 IA , I I Well Type Inj. w TVD 5660 1100 2520 2470 2470 P.T.D 1950920 TypeTest SPT Test psi 1500 OA 260 340 340 ! 340 I I Interval 4YRTST P/F P ./ Tubing 2075 2075 2075 I 2075 I Notes: Pretest pressures observed and found stable. Well demonstrated good mechanical integrity. ./ 5CA.~NED JUN· 2 1 2007 Wednesday, June 06, 2007 Page I of I 08/22/06 Scblumbepgep RECE\VED NO. 3936 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth r. C) ((:: L1 (,;' 0 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 AUG 2 3 2006 SCANNED ~ commission :"Jas'¡{â Oil & Gas Gons. . And10rage UI~ »OOñt ¡t7S--CA8 Field: Kuparuk Well Job# Log Description Date BL Color CD 2E-05 11249943 SBHP SURVEY 08/08/06 1 1J-109 11235392 CBUUSIT 08/07/06 1 30-11 11213793 LDL 08/14/06 1 2T -28 11235394 INJECTION PROFILE 08/16/06 1 1 H-17 11213794 PROD PROFILE W/DEFT 08/15/06 1 1 L-22 11235395 INJECTION PROFILE 08/17/06 1 1J-166 40013010 MD VISION RESISTIVITY 01/19/06 1 1 1 J-166 40013010 TVD VISION RESISTIVITY 01/19/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . 01/27/04 Schlumberger NO. J10Q Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-5711 Attn: Lisa Weepie A TTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk ( Well Job# Log Description Date BL Color CD I'6L} '053 2A-04 10709682 INJECTION PROFILE 12/27/03 1 95~ 2T-28 10709867 STATIC SURVEY 01/15/04 1 \'ÖLf";c:' 2A-04 10709691 RST 01/19/04 1 ~~ )~rJ.- 2 K -01 10696828 LDL 01/14/04 1 )11')" (3 ~ 1 D-140 10696827 LDL 01/13/04 1 101-1' \ 3H-03 10709688 PRODUCTION PROFILE 01/16/04 1 O~3' ~5~ 2P-447 10696819 SCMT 01104/04 1 C8~ JS3 2P-434 10709667 USIT/CBL 12/02/03 1 01103/04 1 ~- ,I Kl9 ~Fi \ 2P-432 10696818 PERF RECORD & SBHP ( -~ --.,.,. - . .. ',' r\~Vt::'Vt:LI , .,...\ .~...~ ,''''~~~ JI\J' 1 ~) (: 2004 SIGNED:"~"~\~ 1 /'\1" '.."\"') ,,0 ð't :t, r- /"\/, DATE: l\h:mka au & Gas Cons, CommÏ8iM\\ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8.317. Thank you. ~',nr,horage SGA~NEtD,: FEB @ 3 2004 ---"'\)''"::--::'>'<--- (r-,." c ,~ MEMORANDUM TO: Randy Ruedrich Commissioner THRU: Jim Regg P.I. Supervisor FROM: State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 14, 2003 ,,,,.,~ SUBJECT: Mechanical Integrity Tests Conoco/Phillips Kuparuk River Field 2T Pad John Crisp Petroleum Inspector NON- CONFIDENTIAL Kuparuk River Unit Packer Depth Pretest Initial 15 Min. 30 Min. Well[ 2T-10 [Typelnj.[ S [ T.V.D. [ 5771I Tu~,n~l2sso 12~0 12~0 12~0 [IntervalI 4 P.T.D.[ 1860960ITypetest[ P [Testpsi[ 3000 [Casing] 1150 I 3080 I 3050 I 3040 I P/F [ E Notes: OA 160 psi, pretest & 170 psi. during test. 3.5 BBL. Pumped. We,,I2T-18ITypelnj.I s I T.v.D. I~o I Tubi~gl240012400 12400 12400 Ilntervall4 P.T.D.I 1950170ITypetestl P ITestpsil 3000 I Casingl 1800 I 2970 I 29501 29401 P/F I E Notes: OA 760 psi. pretest & 900 psi. during test. 2 BBL. Pumped. We,I 2T-2S IType,nj.I S I T.V.D. 157~3 I Tubing| 2aao 12aao 12aao 12330 I,nte,w,I 4 P.T.D.I 1950820 ITypetestI P ITestpsiI 3000 I Casing! 1020 I 3040 I 3000 I 3000 I P/F I --P Notes: OA 0 psi. during test. 2 BBL. Pumped. We,,I=~-=~ IType,.J.I sI I, erv ,l4 P.T.D.I 1950920I -Typetestl P ITestpsil 3000 I Casingl 1340 I 3050 I 3000 I 2980 I P/F I P Notes: OA 0 psi. during test. 3 BBL. Pumped. we,,I2T-29ITypelnj.IGI T.V.D.Ilntervall4 P.T.D.I 1950750ITypetestl P ITestpsil 3000 ] CasingI 240 I 2950 I 2925 I 2910 I P/F I 13 Notes: OA 0 psi. during test. 5.4 BBL. Pumped, Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I travded to C/P's Kuparuk River Field to witness 4 year MIT's. No failures witnessed. /,: M.I.T.'s performed: _5 Number of Failures: O Attachments: Total Time during tests: 4 hrs. cc: MIT report form 5/12/00 L.G. 2003-0614_M IT_KRU_2T-29_jc.xls 6/24/2OO3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state. ak.us and Bob_Fleckenstein@admin.state. ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk/KRU/2T 06/14/03 Sauvageau/Brake - APC John Cdsp Well J2T-t0 P.T.D. IlSe09e0 Notes: Packer Depth Pretest Initial 15 Min. 30 Min. Type Test Test psiI 1500 I Casingl 11501 30801 30501 30401 P/F I P Well J2T-t8 P.T.D.11950170 Notes: Type Test Test psiI 15oo I Casing I 18001 297°1 295°1 29401 P/F I P Well J2T-26 P.T.D.I JS50820 Notes: Type Test Test psiI 1500 I Casingl 10201 30101 3O001 30001 P/F I P P.T.,D.I~9S0920 Type Test Test psiI 1500 I Casingl 13401 30501 30001 29801 P/F NOtes: P.T.D,I~'950750 TypeTest Test psiI 1500 I Casing I 2401 29501 29251 29101 P/F Notes: P.T,D.I~951020 Type Test Test psiI 1500 I Casing I 13001 30501 30001 30001 P/F Notes: P.T.D.I~95~220 TypeTest Test psiI 1500 I Casing I 13501 29501 29201 28751 P/F Notes: Carried MIT out for one hour Pressure at 45 min 1100/2820 1 hr 1100/2800 Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting MIT Report Form Revised: 05/19/02 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test 2003-0614_M IT_KRU_2T-10_-18_-26_-28_-29 -36 -201 .xls INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover O = Other (describe in notes) 612512003 '~(RU 4 yr MIT's 2K & 2T Subject: KRU 4 yr MIT's 2K & 2T Date: Sun, 15 Jun 2003 16:23:23 -0800 From: "NSK Problem Well Supv" <nl 617~conocophillips.com> To: bob_fleckenstein~admin.state.ak.us, jim_regg~admin.state.ak.us, tom_maunder~admin.state.ak.us CC: "nl 617" <nl 617~conocophillips.com> Tom, Bob, Jim, Attached are the 4 yr MIT's for injection wells on 2K and 2T. Please let me know if you have any questions. MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224 (See attached file: MIT KRU 2T 06-14-03.xls) (See attached file: MIT KRU 2K 06-14-03.xls) MIT KRU 2T 06-14-03.xls Name: ~_~MIT KRU 2T 06-14-03.xls Type: EXCEL File (application/msexcel) Encoding: base64 ~[~MIT KRU 2K 06-14-03.xls] Type: EXCEL File (application/msexcel) I i .}Encoding: base64 ~1 1 of I 6/25/2003 1:45 PM 04:4Zpm F rom-k4ARATHON 01L +g155848485 T-881 STATE OF ALASKA ALASKA OIL AND GAS OONSEF{VATION COMMISSION APPLICATION FOR SUNDRY APPROVALS P.OZ/05 F-646 Type of Request: Abandon Suspend Operation Shu~own Re-enter Suspended Well Alter Casing ~ Repair Well ~ Plugging ~ Time Extension ~ S~imulate X Change Approved Program Pull Tubing Variance Perforate O~er 2. Name of Operator ,. MARATHON OI[.'COMPANY Address P. O. Box 196168, Anchorage, AK 99519.6168 4, Location of WellatSud~c~ 1t64' FNL, 1487' FWL, Sec. 34, T7N, R10W, $.M, At top of Productive lateral 1151' FNI.: 1579' FWL, Sec. 34, -I-/N, R10W, S.M. @ 9107' TVD At Effeclive Depth 1234' FNL, 1925' FWL, ~e~, 34, TTN, R10W, S.M. ~ 10337'TVD At To~l Depth 17~6' FNL, 1889' FWL= Bec. 84, T7N, R10W, 8. M. @ 15610'TVD Type of Well; Development 12. PresentWell Gondition Summary Total Depth; measured 16928 feet true vertical 15610 feet EXploratory Stratigraphlc~ Service 6, Datum Elevation (DF or KB) 186' KB MSL feet ?. Unit or Property Name De~ver Creek Unit 8, Well Number BC-6 . . 9. Permit Number 95-092 10. APl Number 50-133-20346 11. Field/Pool Beaver Creek Field, Tyonek 10400',11200',11360',14447',14647. 15280',15280' . Pluga (measured) Eh~octive Depth; measured 10400 feet true vertical 10337 feet Junk (measured) Fill- 10370 (5/24/99) Casing Structural Conductor Surface Intenmedl~e Production Liner Perforation Depth; measured true vertical Leng~ Size Cemented 4022 13-~8" 2400 sks 12410 9-5/8' 3388 $B~4 7" 652 1208 5" 450 9120'-9155',9866'-9886' 9107'-9141' 9824'-9844' Measured Deplh True Vertical Depth 4022 4022 12410 12228 14980 14674 15889 18681 Tubing (sic, e, grade, and measured depth) ,3-1/2', 9.2~, N-80 to 8998' Packers and SSSV (type a~d measured depth) Baker model 194 SAD 40x32 Packer @ 69t 1' 13. Attachments Description Summary of Propoe~l ~ Detailed Operations Program ~X BOP Sketch 14, Estimated Date for Commencing Operation 15. statue of Well Classification 6-Mar-01 16. If Proposal wee Verbally Approved OII Gas X Name .of Appmver __ Date Approved ~ervice 17. I her'et~'~ that the foreg~ls true and correct ~ ~e best of my knowiedge, $~jned ~ ~ ~ ~t~ r, Gary Eller Title Production Engineer '- -' ' ' '~ FOI~ C~)MMISSlON USE 0'NL~' Cond Mon~ of ApPr~a Noti~oom~ls's on ~o repreaenta,~iV~' may wi~ess Suspended~ Date 2/26/01 Plug Integrit7 ~ BOP Test Location Clearance Mechanical Integr~ Test_,_. ~ubsequent Foam R~luired 10- -'-~ ~'~ Approved by Order of the Oommis~ion Rev, Submit in Triplicate RECEIVED 2 6 2001 Alaska 0ii& Gas C~s. C0~ And~m'a~. Feb-~6-01 04:4Zpm From-MARATHON OIL T-831 P.03/0~ F-848 Well BC-6, Beaver Creek Field AFE 8102901 Fracture Stimulate the Tyonek Sand Fracture stimulate the Tyonek Sand in well BC-6 to increase production rate. Proced,ure: 1. Lay down seamless, impermeable liner and felt on the drilling pad as per the attached schematic. The frac tan~ and frac iron will be placed on one section of pad, and the flowback tanks and flowback iron will be placed on a separate section of liner. 2. Move in two 500-bbl horizontal frac tanks and spot on the liner. Prior to arrival in the field, the tanks should be hydrostatic tested and visually inspected for cleanliness, adequate access to hatches, adequate relying, and having plugs in all outlets. 3. Move in the sand silo and spot on the liner. 4. Move in the flowback manifold and the flowback tank onto the liner as per the attached diagram. The flowback tank should be at least 150-bbl capacity, closed top, and be equipped with adequate access for vessel cleaning. It should be equipped with three 602 thread-half fittings and diffuser plates where the flowback lines will tie into. The flowback manifold (see attached) is a 2", 5M, 5-way manifold. The towlines will be 2-3/8" tubing with 602 and/or 1502 fittings. The towline segments should have pollution containment at least at every joint. RU to the wing valve and pressure test lines to 5000 psi using diesel. 5. Load the sand silo with the designated amount and type of proppant. 6. Move-in and install 4" wooden sills around the edge of the entire lined area to provide a berm. Lap the top of the liner over the sills and tack the liner in place with strips of timbers. Leave a portion of the berm removable where the diesel tanks and frac iron will have access when necessary. 7. Fill frac tanks with the designated amount and type of diesel (initial estimate = 700 bbl). Watch for drips and leaks in the frac tanks during the loading operation. Check the tank level routinely during filling operations. Leave at least 1' of each tank unfilled. Adequate sorbents should be on hand during the filling operation, and for the remainder of the job. After releasing the diesel delivery trucks, replace wooden sills to complete the bm~n. Accurately record the volume of diesel in each frac tank. 8, MIRU BI pump truck onto the tree top of BC-6. Tie-in radioactive tracer supply on the Iow- pressure side of the pump truck, Pressure test lines to 5000 psi, Ready equipment to record treating and falloff pressure data. Pump diesel (volume to be determined) tagged RECEIVED 2 6 2001 Alaska Oil & Gas Cons. Commission Anchorage Feb-26-01 04:4Zpm From-MARATHON OIL +9166646469 T-631 P.04/05 F-846 Well BC-6 Beaver Creek Field AFE 8102901 Page 2 with radioactive tracer down the tubing of well BC-6. Cut off tracer and flush with diesel to the top perf. RDMO pump truck and tracer hand. Strap the remaining volume of diesel in the frac tanks. 9. MIRU slickline unit. Pressure test BOPE to 3000 psi. RIH with gauge ring to TD. POOH. R.IH with gamma ray/CCL log to TD, and log across entire perforated section. POOH, RDMO slicldine. Send log data to Anchorage engineer. 10, Reload frac tanks with diesel if needed. 11_ Mob frac iron and tree saver onto liner of well BC-6. Finish installing berming material at this point if there is any remaining to be done. 12. MIRU hot oil truck. Position hot oil truck as far away from diesel frac tanks as is feasible. RU the hot oil truck to circulate diesel from one of the frac tanks. Heat the diesel in the frac tank from ambient temperature to 90 ° F. Repeat this process for each frac tank. RDMO hot oil truck. 13. Mob frac personnel, tree saver personnel, flowback personnel, and fire fighting personnel. Install 3W', 10K tree saver on well BC-6 and test to 9500 psi. Pump diesel based frac stimulation down well BC-6 as per sepat-ate procedure. When finished, bleed surface pressure below 4000 psi and RDMO tree saver. RDMO frac crew and frac iron. Release fire fighting crew and tree saver crew. Strap remaining volume of diesel in fi-ac tanks. Use a roustabout crew to cleanup any diesel spillage as early as practical. 14, As soon as is practical, initiate flowback of well BC-6 through the frac manifold. Flowback should be fairly aggressive since the frac fluid will not be energized with nitrogen. Continue flowback as per instructions on the Production Engineer. When the well is cleaned up sufficiently, RDMO flowback iron. Turn well over to the Production Department to produce. Clean the flowback tank adequately for transpmx, and ship any exempt waste (i.e. proppant, diesel, produced water, etc.) to the G&I plant for disposal. JGE - Februm3r 26, 2001 RECEIVED 2 6 2001 Aia~ka Oil & Gas Co~s. Commis~n Anchorage Feb-~8-01 04:42pm From-MARATHON OIL ', Camco Injection M.',ndml (987.~-994,-% OD:5.890,1g;2.~92) 80-40 K-Anchor (6999.9,~911.0, BaKer le4 SAB 40X32 Pa~l~r (8911 Nipple (~g65.g.6~07.3, O0;3,g50, 10:2.813] Carr~o X Nipp!~ (896! ..5-B90~,1~, 0D:4.050, V~rellrte I~eont~ Guide (.~7.3-8998.0, 0D;~,867, ID:2.g5~2) P~ (9120,0-~155.0) Fill (10388,0,10400.0, 0D;8,825) Ref~iner (~040D.0,10406.0, QD:8.981) Rm,~iner (11200.0-t121Q.0, Cement (.113~0.~1 Pa~k~r (1144&0-I'1 ¢53.0, 0D:8.95~) Cement (114~6.0.115E~0,0, P,:x~uctlon ~.iner (1144~.0-146~0.~, OD:?.O00, C-~ment (14447.0-14547,0, OD:~.la~ Bridge i~l~g (.14647.o-14~55.0, QD'.{~.184) Liner (1408%0.1~BB9.0, OD:5.aOO, VW. 1 ~,~o) C~ment (15,?,60.0.15280.0, OD~4.018) [~udg~ Pl~9 05280 0-1628B.0, 00:4,036~ +9155645489 BC- 6 T-B31 P.OB/O$ F-B4B ..... I~-"t s (70~ o') I~.'1~ (705o,) ........... B.16L {7130') ........ 647 Ulg5') ................ B4 B (7200') .................... I~-1~ (735o'). · B.20 0'460') .... ~-2~ ¢520') ............. ~-23 C7~o') ..... ~.24 · . U, Tymnek (91203 APl 50-133-20346 RECEIVED 2 6 2001 AJaska Oil & Gas Co~s. Commission Anchorage 6120/97 O4:4Zpm From-MARATHON 0IL +gl$$B4B4Bg T-B31 P.01/05 F-B46 AlaskaP I '~ Domestic ! ,duction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 FAX COVER LETTER PLEASE DELIVER THE FOLLOWING TO: Name: Company: Fax No,: Number of Pages (in=iuding cover page): ~ FROM: tLooation/Extension: ,o.-. .... 907/564-6489 NOTE: ff transmission is not complete, please call 907/561-5311. A subsidiary of USX Corporation EnvironmentalLy aware for the long run. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION "~ GAS WELL OPEN FLOW POTENTIAL TEST REPORT la. TEST: INITIAL X lb. TYPE TEST STABLILIZED ~"t NON STABILIZED ANNUAL MULTIPOINT X CONSTANT TIME SPECIAL OTHER I SOCHRONAL . 2. Name of Operator 7. Permit No. Marathon Oil Company 95-092 3. Address 8. APl Number 3201 C Street, Ste. 800, Anchorage, Alaska 99503-3934 50- 133-20346 4. Location of Well 9. Unit or Lease Name At surface Beaver Creek Unit 1487' FWL & 1164' FNL .10. Well Number Section 34, ']'TN, R10W, S.M. BCU-6 11. Field and Pool Beaver Creek Field, Tyonek 5. Elevation in feet 16. Lease Designation and Serial No. 185'MSLI A-028083 4/97 15928 10406 (retainer) Single tbg. string/cased hole 16. Csg. Size Weight per foot, lb. I.D. in inches Set at ft. Perforations: From To 9.625 47 8.681 12410 9120-9155 Upper Tyonek 17. Tbg. Size Weight per foot, lb. I.D. in inches Set at ft. 9866-9886 Tyonek D-1 3.5" 9.3 2.992 8998 18. Packer set at ft. 119. GOR cf/bbl. 120. APl Liquid Hydrocarbons 21. Specific Gravity Flowing fluid (G) 6911I ....I 0.56 22. Producing thru: Reservoir Temp. °F. Mean Annual Temp. °F. Barometric Pressure (Pa), psia Tbg. r'~- csg.' ....... 121 33 14.73 23. Length of flow channel (L) 9120 I Vertical Depth (H)I 9107 Ga. °/° CO2I 0.2 %N2 0.6 °/°"2S I Pr°ver 0 Meter runl Taps X 24. Flow Data Tubing Data Casing Data Choke Prover Orifice Line Size X Size Pressure Diff. Temp. Pressure Temp. Pressure Temp. Duration of Flow No. · (in.) (in.) psig hw °F. psig °F. psig °F. Hr. 1. 3.826 X 2 684 2.85 67 2350 53 .... 24.000 2. 3.826 X 2 700 4.2 67 2200 53 .... 24.000 3. 3.826 X 2 702 4.1 67 2060 53 .... 24.000 4. 3.826 X 2 702 4.6 72 1870 53 .... 24.000 5. X Basic Coefficient (24-Hour) hwPm Pressure Flow Temp. Factor Gravity Factor Super Comp. Factor Rate of Flow No. Fb or Fp Pm Ft Fg Fpv Q, Mcfd 1. 46.6 44.2 698.7 0.9933 1.336 1.1447 2,057 2. 48.9 54.2 714.7 0.9933 1.336 1.1442 2,649 3. 55.6 53.6 716.7 0.9933 1.336 1.1424 2,981 4. 58.9 56.8 716.7 0.9887 1.336 1.1372 3,345 5. Fig 3-30 GPSA Temperature for Separator Gas for Flowing Fluid No. Pr T Tr Z Gg G 1. 1.0025 527 1.542 0.7632 0.56 2. 1.0259 527 1.542 0.7638 3. 1.0289 527 1.542 0.7663 Critical Pressure ~ ~ ~ I~ % ~/!~ ~ 4. 1.0289 532 1.557 0.7733 Critical Temperature ~r~ ~.,,~. ~ ~ V ~? [J 5. Form 10-421 CONTINUED ON REVERSE SIDE .... ~,, i x ~"' Submit in Duplicate 0 ~s~a, ~il ~ ~,o, ~;o~s..C0mmi~:~., ..... Pc 2,950 Pc' 8,702,500 Pf PF 0 No. Pt Pt2 Pc' - Pt2 Pw Pw2 Pc' - Pw~ Ps Ps2 PF - Ps~ 1' 2,350 5,522,500 3,180,000 .... 0 0 2. ! 2,200 4,840,000 3,862,500 ...... 0 0 3. 2,060 4,243,600 4,458,900 ...... 0 0 4. 1,870 3,496,900 5,205,600 ...... 0 0 5. 0 0 25. AOF (Mcfd) 10,428 n 1.0193 Remarks: 4-point test conducted June 21-26, 1997, using wellhead gauge recorders. I hereby certify that the foregoing is,.t, ru.~ and correct to the best of my knowledge. Signed //_~, Title Reservoir Engineer Date 10/10/97 DEFINITIONS OF SYMBOLS AOF Fb Fp Fg Fpv Ft G Gg GOR hw H L n Pa Pc Pf Pm Pr Ps Pt Pw Q Tr T Z Absolute Open Flow Potential. Rate of Flow that would be obtained if the bottom hole pressure opposite the producing face were reduced to zero psia. Basic orifice factor Mcfd/ hw/Pm Basic critical flow prover or positive choke factor Mcfd/psia Specific gravity factor, dimensionless Super compressibility factor = I/Z dimensionless Flowing temperature factor, dimensionless Specific gravity of flowing fluid (air = 1.00), dimensionless Specific Gravity of separator gas (air=1.00), dimensionless Gas-oil ratio, cu. ft. of gas (14.65 psia and 60° F.) per barrel oil (60° F) Meter differential pressure, inches of water Vertical depth corresponding to L, feet (TVD) Length of flow channel, feet (MD) Exponent (slope) of back-pressure equiation, dimensionless Field barometric pressure, psia Shut-in wellhead pressure, psia · Shut-in pressure at vertical depth H, psia Static presssure at point of gas measurement, psia Reduced pressure, dimensionless Flowing pressure at vertical depth H, psia Flowing wellhead pressure, psia Static column wellhead pressure corresponding to Pt, psia Rate of flow, Mcfd (14.65 psia and 60°F.) Reduced temperature, dimensionless Absolute temperature, degrees Rankin Compressibility factor, dimensionless Recommended procedures for tests and calculations may be found in the MANUAL OF BACK-PRESSURE TESTING OF GAS WELLS, Interstate Oil Compact Commission, Oklahoma City, Oklahoma Form 10-421 Rev, 7-1-80 95 ..... O92 95--092 95--0a0 9~., .... 09o~. 95 ..... 09° A 0,3 C C I n d '¥ v '¥ d u a 'J ~,,,I e 'i 'i -'.3eologicai Ha'Eer"'¥als Znventor"y 09/' '/0/"95 08 / ~! 9 E, CBT ~9:}00 10'732 1 OB lo/ .5 CDR IJStT 0890 07 h. 6 i 09,/'i O/9B 1 08/' i 8/"95 iO a07 C.$R'"ISOHF'LETION DATE DAZLY WELL OPS Yt a s dr'y di"tcl'~ sarnples Lhe well cor'ed:? Ar'e wel 1 We-! 'l i s C 0 lq kl E N T S r' e q u i' r"e d ? y e s ~?~ i'~ d i"e c e i v e d ? y ~ yes i~Ana"iysis & descr'ip't:'ior'l r'eceived? y~~ R e c e 'i v e ,d: ~ ARCO Alaska, inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 26, 1995 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2T-28 (Permit No. 95-92) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the recent operations on KRU 2T- 28. If there are any questions, please call 265-6206. Sincerely, Supervisor Kuparuk Drill Site Development MZ/skad STATE OF ALASKA I _. ALASKA OIL AND GAS CONSERVATION COMMISSION - WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OiL E~ GAS [~] SUSPENDED [-'-] ABANDONED [~] SERVICE r~ Classification changed to Water Injector 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 95-92 3 ,~ddress 8 APl Number P.O. Box 100360, Anchoracje, AK 99510-0360 .,¢~-. 50-103-20225 4 Location of well at surface .~i9 .. Unit or Lease Name 507' FSL, 556' F'WL, Sec. 1, T11 N, R8E, UM ;TM~¥'~"~:'~';0~ i ~ .;~ ~.-,~. " ~!~-- :.~-~'-¢-j~t~ ~ .Kuparuk River Unit ~"" ;' ' i~ At Top Producing Interval ? ~'~, l~ ;~ .~,;z-:~,;,~ !~ 10 Well Number 1821' FNL, 1479' F'VVL, Sec. 36, T12N, R8E, UM ..... " ......... =-'~; :~ KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. Kuparuk River Oil Pool RKB 41', Pad 81'} ADL 25548 ALK 2662 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 16 No. of Completions June 26, 1995 July 2, 1995 11 -Sap-95 (perfd) NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set'1 21 Thickness of permafrost 10890' M D & 6058' TVD 10794' MD & 5986' TVD YES X~J NO L_JI NA feet MDI ., 1380' ss APPROX 22 Type Electric or Other Logs Run GR/CDR, G R/CCL./USlT~BT 23 CASING, LINER AND CEMENTINGREC, ORD~.~ SETTING DEP:I'H MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT 9.625" 40.0# L-80 Surf. 4274' 12.25" I Lead, 670 ~ . 7" 26.0# L-80 Surf. 10877' 8.5' 236 sx Class G ..~ 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 10381' 10354' 10473'-10493'MD 4spf 5746'-5761'TVD 10534' o 10562' MD 4 spf 5792' - 5813"I'~D 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 10590' - 10608' MD 4 spf 5834' - 5847' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10616' - 10628' MD 4 spf 5853' - 5862' TVD i ., 27 PRODUCTION TEST ,, Date Firsl Production Method of Operation (Flowing, gas lift, etc.) September 16, 1995 (injecting), Water njector Date of Test Hours Tested PRODUCTION FOR IOIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAs-oIL RATIO I TEST PERIOD E~ Flow TubingICasing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. I ,24-HOUR RATE ~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. .~. .. ...~ Form 10-407 Submil in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SiDE 30. i . GEOLOGIC MAF~E~ FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 10465' 5740' Bottom Kuparuk C 10494' 5762' Top Kuparuk A 10516' 5778' Bottom Kuparuk A 10689' 5908' 31. LIST OF A'FFACHMENTS Directional Survey, Daily Drilling Report 32. I hereby certifl/ that the foregoing is true and correct to the best of my knowlege. 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- 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". Form 10-407 Date:10/05/95 Page: ! ARCO Alaska Inc. DAILY DRILLING REPORT WELL:2T-28 RIG:PARKER 245 WI: 55% SECURITY:0 WELLID: AK8229 AFE: AK8229 TYPE:DEV AFE EST:$ 1465M/ 1910M AREA/CNTY:NORTH SLOPE STATE:AK API NUMBER:50-103-20225 FIELD: KUPARUKFIELD SPUD: START COMP: FINAL: 06/26/95 (1) TD: 121' (121) SUPV:RLM 06/27/95 (2) TD: 3396' (3275) SUPV:RLM 06/28/95 (3) TD: 4285' (889) SUPV:JT 06/29/95 (4) TD: 4795' (510) SUPV:JT 06/30/95 (5) TD: 5920' (1125) SUPV: JT 07/01/95 (6) TD: 9306' (3386) SUPV:JT 07/02/95 (7) TD:10763' (1457) SUPV:JT 07/03/95 (8) TD:10890' (127) SUPV:JT 07/04/95 (9) TD:10890' ( 0) SUPV:JT MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 FUNCTION TEST DIVERTER Move rig from 2T-22 to 2T-28. Accept rig at 0230 6/26/95. DAILY:S47,592 CUM:$47,592 ETD:SO EFC:$1,512,992 MW: 10.0 - PV/YP: 30/28 APIWL: 7.4 CIRCULATE Spud at 0730 hrs 6/26/95. Directional drill 12.25" hole from 121' to 3396'. DAILY:S74,461 CUM:$122,053 ETD:SO EFC:$1,587,453 MW: 10.0 PV/YP: 19/ 9 APIW-L: 5.8 CEMENTING Drill from 3396' to 4285' Run 9-5/8" casing. Prepare to cement. DAILY:S197,695 CUM:$319,748 ETD:SO EFC:$1,785,148 MW: 9.8 PV/YP: 21/19 APIWL: 7.2 DRILLING Cement surface casing. CIP at 0830 on 6/28/95. Drilled from 4245 to 4795'. DAILY:S130,345 CUM:$450,093 ETD:SO EFC:$1,915,493 MW: 9.8 DRILLING Drilled from 4795' to 5920'. DAILY:S83,819 CUM:$533,912 PV/YP: 14/11 ETD:SO APIWL: 7.4 EFC: $1,999,312 MW: 9.7 DRILLING Drill from 5920' to 9306'. DAiLY'S71,945~u~,~.$605~$~-7 PV/YP: 19/ 8 ETD:SO APIWL: 6.8 EFC: $2,071,257 MW: 10.8 DRILLING Drilled from 9306' to 10763' DAILY:S93,861 CUM:$699,718 PV/YP: 15/10 ETD:SO APIWL: 4.8 EFC: $2,165,118 MW: 10.8 PV/YP: 18/ 9 APIWL: 4.4 RUNNING CASING Drilled from 10763' to 10890'. Run 7" casing. DAILY:S81,522 CUM:$781,240 ETD:SO EFC:$2,246,640 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 ACCEPT RIG @ 2T-31 Finish running 7" casing. Cement casing. Freeze protect well. Release rig @ 0400 7/4/95. DAILY:S207,529 CUM:$988,769 ~TD:$0 EFC:$2,454,169 7". ; .., ~-~ ~ = ~ ' ..~ Date: 10/05/95 Page: 2 ARCO Alaska Inc. DAILY DRILLING REPORT REMEDIAL AND COMPLETION OPERATIONS WELL: WELLID: AK8229 AREA/CNTY: FIELD: SPUD: RIG:NORDIC WI: 0% SECURITY:0 AFE: AK8229 TYPE:DEV AFE EST:$ 1465M/ 1910M STATE: API NUMBER: START COMP: FINAL: 08/30/95 (10) TD:10890' PB:10794' SUPV:MDD RIH WITH 3-1/2" COMPLETIO MW: 8.6 SEAWATER Move rig from 2T-27 to 2T-28. Function test BOPE. Run in hole with packer and 3-1/2" completion. DAILY: $32,100 CUM:$1,020,869 ETD:S0 EFC:$2,486,269 08/31/95 (11) TD:10890' PB:10794' SUPV:MDD RIH WITH 3-1/2" COMPLETIO MW: 0.0 Continue PU and RIH with 3-1/2" completion string and packer. Freeze protect. Secure well. Rig released at 1800 hrs. 8/30/95. DAILY:S107,880 CUM:$1,128,749 ETD:SO EFC:$2,594,149 9/11/95 Complete perf 'A' sand interval 10473'-10493', 10534'-10562', 10590'-10608', and 10616'-10628' as ref USIT dated 8/4/95 using 2-1/8" EJ with alternating BH/DP charges, 4 spf, 0° phasing, 0° orientation. End of WellSummary for Well:AK8229 .. ~,,~, PROGRAM LOCATION 1 KUPARU~ LOCATION 2 ALASKA ~sC~INATIUN 28 GRID CONU~R~HC~ ANGL~ 0,00 DAT~: 02-JUL-?~ W~LL HUMBER O ~LL H~AD LO,AT!OH.: LATfH/-.S) 0,00 DEP(;~/-~) 0,00 AZIMUTH FROM RD?ART TAB£~ TO TARgeT !~ 6,21 TIE iN POINT(TIP) i MEASURED D~P?H 12!,00 TRUE U£RT D~PTH 121,00 ~,.~ ? · LATITUDE(N/-~) 0,00 DEPARTUR~(E/-~) 0,00 M£ASUF'.D~ IN'!'£RV~L VBF,'T!CA£ b£PTH ~..,..," '=" .,00 ,~:,0.. 279,55 19.~,:, a,,: .,,.~ 441,,,.~, v'~' 61,5 440,,4'9 =.5 t ,. .... ?O" '.-.,30, 62.2,00 BO2,00 ,-vlO,eT.~, I!0!,75 1!75,73 1382o21 IASn,,= 1943,~2 2317,t-': 7599,47 3257,48 4939" 5024,17 ~ "" '~ "" 7i5,7'6 iO05,OS ?!,I """~ 73,~ I152,19 73,'? i27i~0! -. ~, Si. ?2,6 '?~,4 !.443~42 "!762,44 !76!,89 2!22,59 93,2 2168,54 ?3,2 2209,62 280,2~.=,g~o! 66 2~8 !84,3 30i4:.21 ~!,2 3057,!5 ¢5,4 3102,~4 ?!,? 3146,47 94,2 3t90,45 ~4,'7 '2250,34 ............. TARG£? "'""*'ION ..... eH'r :~,~ ~ZII'JLITH :,.A?I,'t'!r,v """ SEC?iON !NCLN, N/-S E/-W dso/ f t de,~ de:', f t f t f t d~,a 1C.'Of t O,OO 0,<, ~';' ":,.gO .... 9,00 '; ,. O(~ r:,O0 0,,';0 0,¢0 O,O0 O,OO '-'J, Ob O,O0 O,O0 O,O0 0,0(' 0,00 .' =A F: 66 40 ~'= ' O,y! 40-=,~ ' '.~ ,..,.-, , . 0,54 0:4~ - ,.,.. , ,.,.: .. 0,54 1,50 i,=.'',,: arS,nO t,37 i,ge.": 1,.36 . '", 4.', .... 1, ~,-" , ,.- . 4,37 q,.:...st-"... 5!,00 '.:., '? 4. a, '.,' q. ,,_ .,: .,. ,=~r .:,.,.47, o3 .... 2,2,.I 9,!4 4,25 ~n,00 !~,27 ~ == I1,~° 1~,.~¢ ~' ~,= O0 24,00 .~4,34 ...... ~.,=5~" ~ I~,8~ 40 ~=l ~,67' i;o,~5 ,. 124,21 24,~ !4.7,0i 19,67 !6,25 i42,v,~' 6i.~07 154,62 23,~?~ ~,67 180,21 21, .... 14,26 i=~ ...... .,.15 Stero 2~~':'' 205',~,' ~e?,~n vv 4~ I!,:~ ~4o,46 87,67 264,4t -, o~ "'* 4a~,76 2Y,.03 !!~'?0 400,23 1!9,07 4!7,57 ~7t =~ 49.79 ?~5i .~ . .... 4~0 5~A,51 46,30 7,5'? 524 ar 'IS~,9A 5a9.~! !4~94 -.. , ,a .......... 4~lZ A07,i7 50,42 ~,:~ s94 '~ ,;~ !47,26 6'" ~''' ....... Ii~,~7 10~i .. . ,~ 54,75 4,2? :~ '= ,~,Io 841,96 ......lOn'~,iO 65,22 ~,43 987,91 I~2,07 I005 ,oa ~'' i0,43. 1862,87 66,70 ., 5,62 i844,21 272.x~ !864 o~ 8,4! 2205,85 ,qA,39 7,I0 2185,07 3!0,62 2207,03 8,09 0,37 '..'.?,A~ ,',", :.',n..,a7 ' 4! .... ;,: :, ,: 7 ..:.,.., I..5 ....... " ~',,~ s-, 93 .,"! ..,. , .a , ,~ 7 l ;. ,~'7 .: ,.,a,., 7042 "" . ,, / .,' .':-'",46 '?', O? ............ v 70 .... "- ~':'x, 0I gl,ar: ' " ...."'~ ,,,.,..., ,,.._ 6,67 :309 S, 8..4 4i9.,04.. olaf,V,' .7,70. "., ,o .;"~ 3200 ,.,., PAGE CALCULATIONS CIRCULAR A~C METHOd******** .~,,~ ft ft ft 5500,07 281,0 3450,47 577~,51 27~,4 3567,08 .~,15 2~4,6 36~4,55 6341,3Z 27:~.2 3802,64 2T-28 7183,05 7466,,07 ~.0£7,27 £~0,0 403S,65 279,3 4!47,9~ 2Bl,? 4334,~5 ~' ~ 4 TARSET STATION AZIMUTH LATITUDE DEPARTURE DISPLAC£M£NT at AZIMUTH DLS SECTION INCLN, N/-$ E/-W ft deq de~ ft ft ft dee !OOft 3621,S~ 63,88 9,47 3588,2? 502,3~ o~o.29 7,97 4133,32 64,65 6,55 4095,19 574,61 4135,31 7,9~ 4385,20 65,12 4,31 4345,77 598,42 4386.97 7,B4 4642,54 66,3? 5,78 4602,37 621,05 4644,08 7,6? 0,65 8305,B1 278,5 9151,46 ?430,04 '27B,6 4897,63 65,.08 2,6~ 4856.?1 ~39.92 4898,,89 7,51 !~iI 5!52,35 66,62 5,90 51tl,05 659,04 5153,36 7,35 1,17 ..s4i0,7~. 65,25 ~,57 5367,93 387,09 5411,/.'~ 7.,~.~o o,53' 5665,02 63,64 3,95 5621,15 710,44 5665,87 7,20 1,01 5916.09 64,46 7,63 5870,93 735,91 5916,~ 7,!4 1,23 9520,72 ?0,7 96!3,00 ?2,3 ?704,00 91.0 ?$00,00 ?6,0 9890,77 90.8 4630,45 6t65,83 63,01 4,72 6119.21 762.90 6166,58 7,1i 4753,33 642!,68 65,69 7,44 6373,61 790,0'6 6422,.39 7,07 4B7t:~2:1 66,75,33 6'4.4~ 3,48 6&,26r13 '~1:4,25 6675,97, 7,01 1,35 4?93,50 6929,31 64,12 5,,66 6879.41 .~.4,49 6~29,84 6,92 0,71 51!5,03 7179,~1 64,1~ 2,74 7129,3B 95~,~5 7180,21 6,32 79~7,01 ?6,2 '~, T ~ ~0,9,1: 92,1 I0268~78 ?4,9 10456,~0 iB8,O 5!55,78 7~o0,60 62,!5 3,54. 7210,t7 857,~ .:60,96 A,/~ 2,34 5200,~ 7341.08 59'60 2,65 7290,65 861,64 7341,39 ~,74 2,?0 5~4~,71 7418,~, 57,00 !,2~ 7368,03 ~64,31 7418,55 6,69 3,12 5302,25 7497,79 55,21 3,65 7447,63 ~67,72 7498,01 6,65 2,77 '~ 7571 5~.~,1~. ,46 53,43 4,58 752! !6 873,01 7571,66 6,.62 2,~3 5413,51 7647,78 51,76 4,43 7597,47 879,02 7648,15 6,60 t,53 5471,45 7719,53 50,09 3,.72 7668,89 ~84,12 7717,67 6,5~ 2,i2 55~,6~ 7790,~3 47,76 2,77 '7740,17 ~88,18 7790°96 6,55 2:~ 5734,20 7??0,20 42,5~ ~ "~ o,~u 7?39,22 902,00 7790,29 6,4~ 1,57 82!0,67 40.85 3,09 ~.t59.62 9t4.7! ~2i0~73 ,~,40 0,53 THE !O~?O,OO i01,4 GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 A'I'TN: Sherrie NO. 9688 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 9/1/95 Field: Kuparuk (Open Hole) LIS Well Job # Log Description Date BL RF Sepia DIR MWD Tape SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. MiC OFiLMED / COMF'AH¥ ARCO ALAS[A COCAt!OH t KUPARU~ CCCA?i~H 2 M~H~?IC D£C~iHA?ION 2~,46 GRID COHUER~HC~ ~NG£~ O,O0 ~ELL NUMB~R 7i0,4o !5d3.1 1.509,42 ...... ' ~7,.)2 1 ~ri ? 1~ ' '- ':i'~" ~J,2~ 4,12 ': .'_ % .i. CU)INC r;4~ I F:,t'r~ ¢ 7~ CH[ ;*'" _ ......... ~."]l,.,' 11 CH[: -30,04 44,42 I,x? Z.i! ..... .. WI, -~ ~7 ~: ~" ' .... ~e /,A -.] ','- ' a~ ' -- -'.:{ d~ , -74., 0,"~ ~ 5 ,.,= '"' 3,00 ':: '~ :"~,?! ~ "" ,: 72 .r,: c= ,,r: .,, , r< Oil ~G~... ~ ~C~: mmi~n 'PA~ NO, ' 2T-2~ CIRCULAR ARC MO TV~ INC_CHG CUMINC_CH~ I.RA?~ AZM_CHG CUMAZM.CHG TURN_RATE ft ft dee dee deqilOOft deq deq deqtlOOft CLOSURE TOOL ?AC£ ~LZ DLSRT - ft d~o degilOOft de~/l~Oft~2 5500,1 3450,47 2,07 63,S~ 0,74 -2,02 9,47 "--0.72 -111,2~ 41,3~ 0,97 0.27 577~,5 35~7,0~ ~,73 ~6.~¢ 0,78 -!,~5 8,22 -~,45 -!22,70 ~,82 1.06 0,03 6063,1 3684,55 -1,75 64,65 -0,69 -1,68 6,55 -0,59 -t2B,24 142,27 0,87 0,07 5341,4 5802,&4 0,47 ,~5,12 0,17 -2,24 4,31 -'O,&I -i24,79,,??.43, 6623,7 3718,5~ ~,27 66,3~ 0,45 1,47 5,7~ ~ ~? . v,~. '~2,71 ?3,37 0,65 0,03 7183,1 4147,~4 1,54 5~,62 0,55 3,22 5,?0 1,15 'I02,20 63,00 1,17 0,03 77~8,0 4334,~ -1,61 63,64 -0,57 -2,62 3,75 -0,~3 -~,22 124,84 1,0! ~0~7,3 4507,I~ 0,82 64,46 O,Z? 3,72 7,68 1,33 -117,56 46,~0 1,23 8305,8 4630,45 -l, 45 63,01 -0,52 -2,96 4,72 -1,06 -~6,49 117,37 1.07 0,05 ~5~?,7 475S,3~ 2,68 65,69 0,75 2.72 7,44 0,76 . -~5,77 43,04 !,28 0,07 8869,5 4871,21 -1,21 64,48 -0,43 -3,9& 3,48 -1,41 -72,71 10~,45 1,35 9!51.5 ,~.50 -0.36 .H.12 .13 2.I7 5.66 0.77 -~5,43 100.96 0.71 0.23 9430.0 5115.03 0.04 64.16 0.01 -2.~1 2.74 -1.05 -V6.51 77.03 0.74 7520,7 5155,?E -2,00 ~2,15 -~,21 0,80 3,54 0.88 -72o30 160,57 2,34 1.55 7613,0 5200,89 -2,56 59.60 -2.77 -0.90 2,65 -0.97 -67,73 I63,20 2.90 0,60 9704,0 5248,7! -2,5g 57,00 -2,85 -1.26 1.28 -!,50 -62,21 I56.27 3,12 0,24 ~SO0,O 5302,25 -I,77 55,2I -t,87 2,37 3.65 2,47 -57,00 132,?~ 2,77 0.36 7690.a 5355,1~ -!,7~ 53,43 -!,77 0,93 4,5~ 1,02 -76,64 6~,85 ~,13 Q,70 9?87,0 54I~,51 -1,47 51,V6 -1,52 -0,15 4,43 -0,1~ -52.02 175,35 1.53 0,63 10079,1 547!,45 -1,87 50,09 -1,03 -0,71 3,72 -0,77 -49,36 162,87 2,I2 0,64 t0173,g 5533,6S -2,3~ 47,76 -2,46 -0,93 2,77 -0,79 -45,6? !63,45 2,57 0,47 I0268,6 5598,~4 -Z.35 45,4! -2,48 1.90 4,68 2,00 -42,69 150,90 !0456,A 5734,?n -2,83 4c,5~ -1,50 -I,18 3,50 -0,63 -54,30 157,4I 1,57 0,70 ~v, eo,6 59~1o88 -1,73 40,~5 ,52 -0.42 ~.09 -0,13 -:e,o~ 171,0~ 0.53 0,3I LAST ~URVE¥ I~ PRDJ£CT~ .o.~,O ~058.5~ O.O0 .~5 O O0 O.OC 3.07 O.O0 .... 08 O,O0 ~ ~ 0,52 . ............................ ARCO Alaska, Inc. Date' August 18, 1995 Transmittal Cf: 9287 RETURN TO: ARCO Alaska, Inc. ATTN: Brian Hebert Kuparuk Operations File Clerk ATO-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items. Please acknowledge receipt and return one signed copy of this transmittal. USIT 8/3/95 7400-9037 Cement Bond Log (CBT) USIT Cement Bond Log (CBT) USIT Cement Bond Log (CBT) Acknowled~ DISTRIBUTION: 8/3/95 7400-901 3 8/4/95 10746-10794 8/4/95 9300-10732 8/4/95 9000-10427 8/4/95 9000-10403 RECEIVED Date: I ' Alaska Oil & Gas Cons. Commission Anchorage Sharon Alisup-Drake DS Development ATO-12O5 Larry Grant (+sepia):, AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Erickson/Zuspan NSK Central Files NSK-box 69 ARCO Alaska, Inc. Date: August 25, 1995 Transmittal #: 9291 RETURN TO: ARCO Alaska, Inc. Attn: Brian Hebert Kuparuk Records Clerk ATO-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following items. return one signed co~y of this transmittal. 2A-18~ Directiona[Survey 5/18/95 4~1~b/'~._~-22~--. O G(~ Directional Survey 5/19/95 ,.~,~~ Directional Survey 6/23/95 ~~ Directional Survey 6/9/95 ~/6~0-2 -__I:2~ Directional Survey 7/2/95 ~-~-~ Directional Survey 5/31/95 ~'~~ ~ -_~I[5.3..1_~ Directional Survey ~~3~. ~ Directional Survey 7/17j.26/g5..1/95 Ackn6wledged: ~"~/~.z~..'"') / ,,,;~,~ ,~--1. to: Please acknowledge receipt and AK7621 AK8213 AK8173 AK8237 AK9229 AK8157 AK8181 AK8253 Mr. Vernon E. Pringle, Jr. DeGIoyer and MacNaughton One Energy Square Dallas, TX 75206 :i'~l~arry Grant (2 copies).~ /0333 3001 Porcupine Dr. Anchorage, AK 99501 ARCO Alaska, inc. Date: August 11, 1995 Transmittal #: 9285 RETURN TO: ARCO Alaska, Inc. Attn: Bdan Hebert Kuparuk Records Clerk ATe-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Ct,,)/,~ 0"~0~2A-18 Sub-Surface Directional Survey ~~u~ey 2A-28 SurveySUb-Surface Directional 2T-22 SurveySUb-Surface Directional Sub-Surface Directional ~'~O'~_.~T-26 Survey 2T-29 SurveySUb-Surface Directional 2T-31Receipt ,Sub-Surface Su rve~/ Directional Acknowledged~ DISTRIBUTIO .'~ Mr. Vernon E. Pringle, Jr. DeGIoyer and MacNaughton One Energy Square Dallas, TX 75206 5/18/95 AK 7621 ~5 AK R2.13 7/2/95 AK 9229 6/23/95 Ak 8173 6/9/95 AK 8237 5/31/95 AK 8157 7/11/95 Date; - ,ct ~;~i ~ ~.. ""' guns Anchorage' :~r~ Gr~t (2 ~pies) 3001 Porcupine Dr. Anchorage, AK 99501 ~ CONSERVATION COM~HSSION ~LASKA OIL AND G~S TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 June 22, 1995 Michael Zanghi Drill Site Development Supervisor ARCO Alaska, Inc.. P O Box 100360 i Anchorage AK 99510-0360 Re: Kuparuk River Unit 2T-28 ARCO Alaska, Inc. Permit No: 95-92 Sur. Loc. 507'FSL, 556'FWL, Sec. 1, TllN, R8E, UM Btmhole LoC. 1666'FNL, 1465'FWL, Sec. 36, T12N, R8E, UM Dear Mr. Zanghi: . Enclosed is the approved application for permit to drill the above referenced well.. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, , Tuckeman Babcock ' Commissioner BY ORDER OF THE COMMISSION dlf/Enclosures Department.of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill [] lb Type of Well Exploratory [] Stratigraphic Test [] Development Oil X Re-Entry D Deepen 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 81' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25548, ALK 2662 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 2O AAC 25.025) 507' FSL, 556' FWL, Sec. 1, T11N, R8E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 1918' FNL, 1441' FWL, Sec. 36, T12N, R8E, UM 2T-28 #U-630610 At total depth 9. Approximate spud date Amount 1666' FNL, 1465' FWL, Sec. 36, T12N, R8E, UM 6/23/95 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2T-29 11053' MD 3614 ~ TD feet 13.0' ~ 575' MD feet 2560 6191' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035(e)(2)) Kickoff depth 400' feet Maximum hole angle 64.38° Maximum~rface 1700 pslg At total depth (TVD) 3200 pslg 18. Casing program Setting Depth size Specifications Top Bottom Quantit7 of cement Hole Casin~l Wei~lht Grade Couplinc, I Lenc, lth MD TVD MD TVD Iinclude sta~le dataI 24" 1 6" 62.5# H-40 Weld 80' 41' 41' 121' 121' _+_200 CF 12.25" 9.625" 40.0# L-80 BTC 4135' 41' 41' 4176' 2872' 860 Sx Arcticset III & HF-ERW 670 Sx Class G 8.5" 7" 26.0# L-80 BTCMOE 11012 41' 41' 11053' 6191' 220SxClassG HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Meas u re,~d~,l;;~th~, ~, = ,~Tr ~/e~/ff~,t[caJ de pth Structural . KELEIVEU Conductor Surface Intermediate Production Liner /\!asker 0il & Gas Cons. Commission Perforation depth: measured Arich0r~ true vertical 20. Attachments Filing fee X Property plat ['~ BOPSketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot E] Refraction analysis E] Seabed report E] 20 AAC 25.050 requirements X 2i' Iherebyc~thatthefIeg°ingistruoandc°rrectt°thebest°fmykn°wledge· ~. Signed Title Drill Site Develop. Supv. Date '{'3"" Commission Use Only Permit Number - ~/API number L'-- I Approval date / ~'~ "3 ..- ~',/'"Fsee cover letter for 2_ -- o I (~ f"~ ' / >1 other recjuirements Conditions of approval Samples required [~ Yes ~] No Mud Icg required ~ Yes [] No Hydrogen sulfide measures ]~ Yes [~ No Directional survey required ~ Yes ~] No Required working pressure forBOPE [~ 2M E] 3M [~ 5M ~] 10M E] 15M Other: 0rigina Signed By Approved by Tuckerman Babcock Commissioner the commission Date . Form 10-401 Rev. 7-24-89 Submit ir~ triolicate , . . 10. 11. 12. 13. 14. 15. 16. 17. GENERAL DRILUNG PROCEDURE KUPARUK RIVER FIELD 2T-28 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (4,176')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (11,053') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) ND BOPE. NU tubinghead & full opening valve and run cased hole cement bond logs. Secure well and release rig. Move in and rig up Nordic #1. Install and test BOPE. Pressure test 7" casing to 3500 psi. Perforate and run completion assembly. Set and pressure test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. RECEIVED JUN 1 4 t995 Al&ska 0il & Gas Cons. C0mmissi0r~ ,~,nch0ra . DRILLING FLUID PROGRAM Well 2T-28 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 50-80* 5-15 15-40 10-12 9.5-10 _+10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 10.9 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur before a surface pressure of 1,700 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 2T-28 is 2T-29. As designed, the minimum distance between the two wells would be 13.0' @ 575' MD. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2T-28 surface/production casing annulus will be filled with diesel after setting 7" and prior to the drilling dg moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the sudace shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface. Risks in the 2T-28 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. The 7" casing will be topset above the Kuparuk and a 5" liner run to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 10.9 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 9-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. ~. [ C E I V [ D Gas Cons. Commission Anch0r~" ARCO ALASKA, Inc. Structure ; Pad 2T Well ; 28 Field : Kuparuk River Unit Location : Norlh Slope, Alaska TD LOCATION: 1666' FNL, 1465' FWL SEC. 36, T12N, RBE I I V ICreated by : jones For: D P~-'~H iDote plotted : 25-May-95 ?lot Reference is 28 Version #4. [Coordinates are in feet reference slot #28. iTrue Vertical Depths ore reference RKB. 5OO .... East --> 550 0 550 11 O0 1650 RECEIVED 5OO lOOO . 1500. _ 2000_ _ 2500_ _ 3000_ _ 3500_ _ 4000_ _ 4500_ _ 5000_ _ 5500_ _ 6000_ _ 6500. RKB ELEVA~ON: 122' N 6.21 DEG E ,JUN 1 4 1995 8183' (TO TARGET)~,i~.st(a Oil & Gas Cons. Commission ***PLANE OF PROPOSAL*** Anch0r,~ TARGET LOCATION: 1918' FNL, 1441' FWL SEC. 36, T12N, RBE TARGET TVD=5890 TMD= 10659 DEP=8183 NORTH 8135 EAST 885 SURFACE LOCATION: 507' FSL, 556' FWL SEC. 1, T11N, RBE KOP TVD=400 TMD=400 DEP=O 3.00 BEGIN TURN TO TARGET T~D=600 TMD=600 DEP=6 8.14 10.66 16.19 ,3 DEG / 100' DLS 21,96 27.83 3X?z B/ PERMAFROST 1¥D=1502 TMD=1561 DEP=299 .... T/ UGNU SNDS TVD=1547 TMD=1615 DEP=328 39.67 45.62 51.5B 57.54 63.51 EOC TVD=2205 TMD=2634 DEP=1090 T/ W SAK SNDS TVD=2214 TMD=2654 DEP=1109 B/ W SAK SNDS '[VD=2672 TMD=3715 DEP=2064 9 5/8" CSG PT TVD=2872 TMD=4176 DEP=2481 K-lO TVD=5064 TMD=4620 DEP=2881 Est. B/ TABASCO TVD=3164 TMD=4851 DEP=5090 MAXIMUM ANGLE 64.38 DEG TARGET ANGLE 40 DEG 500 0 500 1000 1500 2000 2500 Scale 1 ' 250.00 K-5 TVD=4542 TMD=8038 DEP=5963 Begin Angle Drop K-5 Estimated Bose Tabasco K-la 9 5/8 Casing Pt Base West Sak Sands EOC Top West Sok Sands Base Permafrost Top Ugnu Sands BEGIN ANGLE DROP TVD=5148 TMD=9440 OEP=7227 ~%:, DROP 2 DEO / loo' B/ HRZ TVD=5692 TMD=IO$90 DEP=8000 TARGET - 3'/ ZONE C (EOD) TYD=5890 TMD=I0659 DP, P=Bt83__ T/ ZONE A TVD=5917 TMD=10695 T/ A3 SNDS TVD=5934 TMD=10717 DEP=8220 -- B/ KUP SNDS TVD=60$8 TMD=10853 DEP=8507 'ID / 7" CSG PT TVD=6191 TMD=I1053 DEP=8436 _8800 _ _8250 _ .7700 _7150 _ _6600 _ _6050 _ _5500 _ _4950 _ _4400 _ _3850 _ _3300 _2750 _2200 _ 1650 _1100 _ _ 550 _ _ 0 _ _ 550 62.00 58.00 54.O0 50.00 46.00 42.00 I I Z O Vertical Section on 6.21 azimuth with reference 0.00 N, 0.00 E from slot #28 I I I I I I I I I I I I I I I I I I I I I I I I I I 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 !Creeted by : jones For: D PL~I'RASH iDote plotted : 25-May-95 iPlot Reference is 28 Version #4. ;~Coordinotes ore in feet reference slot #28. !True Vertical Depths are reference RKB. Scole 1 · 10.00 100 80 60 40 20 300. . 280. 260 240 1 1 I I 11oo 8O 60 140C 40 2O 0 ,0 1 O0 80 6t9.~ Scale 1 : 10.00 1300 17oo 1600 1500 4O ARCO ALASKA, Inc. Structure : Pad 2T Well : 28 Field : Kuparuk River Unit Location : Norlh Slope, Alaska East --> 0 20 40 60 80 1 O0 120 140 1500 1800 1500 1400 70o 1300 1400 1200 1300 1600 100 7OO 500 1100 1000, 9o0 1200 1200 1300 1400 5O0 II00 2100 lOO 20 40 60 East 160 180 I I I 200 220 1600 3300 80 100 120 140 160 180 200 220 > 160 A I I Z O Created by : jones Fol': D PETRASttl !Date plotted : 25-May-95 Plot Reference is 28 Version !Coordinates are in feet reference slot #28. i True Vertical Depths, are reference RKB. Scale 1 · 20.00 /X I I RECEIVED ARCO ALASKA, inc. Structure : Pad 2T Well : 28 Field : Kuparuk RiveK Unit Location : Nodh Slope. Alaska I 2O0 1040 _ 1000_ 960 _ 920 _ 880 84O 800. _ 760 _ _ 720 _ _ 680 _ 64O 6OO 560 _ -- 520 _ _ 48O 440 400 360 320 Eas± --> 160 120 80 40 0 40 80 120 160 200 24-0 280 320 .560 400 44.0 t 960 10 320O I 920 2100 880 84O .~300 ;100 8OO 760 2100 2000 22OO 2000 3000 720 680 1900 t, 1800 19OO 1800 ~900 2800 2100 640 6O0 56O 520 1900 1700 1600 1700 1900 480 440 400 360 1900 1800 1500 O0 1800 320 280 200 160 120 80 40 0 Scale 1 · 20.00 40 80 120 East 160 200 > 240 280 320 360 40O 440 280 I I Z 0 ;Creeled by : jones Fo[': D P~-"~RASNi iDate piotted : 25-May-g5 ]PIct Reference is 28 Version iCoordinetes ere in feet reference slot #28. i iTrue Verticot Depth~ 9r~ reference RKB. Scale 1 · 50.00 A I I 600 2800_ _ 2700_ 2600 2500 _ 2400, 2500_ _ 2200_ _ 2100_ _ 2000_ 19001 1800~ _ 1700_ _ 1600_ _ 1500_ _ 1400_ _ 1300_ 1200_ _ 1100_ _ 1000_ 500 400 I I I 3100 3000 t300 3200 3100 29OO 28OO 3OOO 2900 500 200 3000 2900 2700 ~2600 25OO O0 26OO t00 I ~ 2500 A co ,aLASKA, Znc. RECEIVED S,ruc, .... ~od 2, We,,,28 ,JUN I 4 1995 Field : Kuparuk River Unit Location : .o~h s,o... ^,o,~t ~sk~. Oil & Gas Cons. Commission Anchor: ,, 24O0 25OO 2200 600 500 400 $00 200 I00 0 Scale 1 · 50.00 East --> 0 I00 200 300 400 600 700 800 900 1000 I i I I I I I I I I II I I I I ~1o0 3oo0 28O0 2600, 25OOl 2800 2401 2700 2600 2300f 22OO 500 I I . 3400 3000 2900 t3300 3200 ~5OO ~300 3100 5400 3500 I00 200 300 400 East --> 3800 3700 360O 500 ¢200 5OO0 4000 3900 4600 450O 44O0 ~9OO tSO0 4700 ¢100 !700 7OO 6OO I I 800 900 1000 _2800 _2700 2600 _ _2500 _ _2400 _ _2300 _ _2200 _ _2100 _ _2000 _ .1900 800 700 600 _1500 _ _1400 _ _1300 _ _1200 _ _1100 000 A I I Z ..UPARUK RIVER UNI'i 20" DIVERTER SCHEMATIC I 4 I 5 3 2 O DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. . , MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20" - 2000 PSi DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSi ANNULAR PREVENTER. RECIEIV£D JUN ~ 4 'i995 Oil & Gas Cons. Commission Anchor~ DKP 11/9/94 < < 7 , 6 5 4 1, 3 13 5/8,, 5000 PSi [--3P STACK ACCUMULATOR CAPACITY TEST CHECK AND Fill ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER UMIT IS 45 SECONDS CLOSING TIM E AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALLOTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, UNES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOl-rOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BUND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILUNG POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILUNG SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL lINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BUND RAMS ON BTM 7. 1;~5/8" - 5000 PSI ANNULAR ....,..L PERMIT CHECKLIST COMPANY WELL NAME GEOL AREA UNIT# PROGRAM: exp [] dev~ redrll [] serv [] ADMINISTRATION 1. 2. 3. 4. 5. 6. ' 7. 8. 9. 10. 11. 12. 13. Permit fee attached ................... Lease number appropriate ................ Unique well name and number ............... Well located in a defined pool ............ Well located proper distance from drlg unit boundary. Well located proper distance from other wells ..... Sufficient acreage available in drilling unit ..... If deviated, is wellbore plat included ........ Operator only affected party .............. Operator has appropriate bond in force ......... Permit can be issued without conservation order .... Permit can be issued without administrative approval. Can permit be approved before 15-day wait ....... ENGINEERING .~PPR DATE 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Conductor string provided ............... ~ N Surface casing protects all known USDWs ........ ~ N CMT vol adequate to circulate on conductor & surf csg..~ N CMT vol adequate to tie-in long string to surf csg . . . Y ~ CMT will cover all known productive horizons ...... .~ N Casing designs adequate for C, T, B & permafrost .... ~ N Adequate tankage or reserve pit ............. ~ N If a re-drill, has a 10-403 for abndnmnt been approved.~---N~ Adequate wellbore separation proposed .......... ~ N If diverter required, is it adequate .......... ~ N Drilling fluid program schematic & equip list adequats .~ N BOPEs adequate ..................... ~ N BOPE press rating adequate; test to ~OO-C..~ psig.~ N Choke manifold complies w/API RP-53 (May 84) ...... _~ N Work will occur without operation shutdown. ~ N Is presence of H2S gas probable ............ ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N//_ 31. Data presented on potential overpressure zones ..... Y N'/ /~--'~F~- 32. Seismic analysis 9f shallow gas zones .......... Y/N . N ~ 33 Seabed condition survey (if off-shore) ........ /~ N / 34. Contact name/phone for weekly progress reports . . ./. Y N [exploratory only] // GEOLOG_~Y: ENGINEERING: COMMISSION: TA~ '~': Comments/Instructions: HOW/jo - A:IFORMS%cheklist rev 03/94 CD I-H .j ' 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 effod has been made to chronologically organize this category of information. ALASKA COMPUTING CENTER ....... SCHLUMBERGER ....... COMPANY NAME WELL NAME FIELD NAME BOROUGH STATE API NUMBER REFERENCE NO : ARCO ALASKA~ /NC, : 2T-28 : KUPARUK RIVER UNIT : NORTH SLOPE : ALASKA : S0-103-20225-00 : 9~23! RECE!VED ~£S Tape Verificaf, ion Li$~,ing Schlumberger Alaska Computing Cenf, er 30-AUG-1995 16:14 **** REEL HEADER SERVICE NAME : EDIT DATE : 95/08/3e ORIGIN : FLIC REEL NAME : 9523~ CONTINUATION ~ : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., KUPARUK 2T-28, API #50-[03-20225-00 · **, TAPE HEADER ,*** SERVICE NAME : EDIT DATE : 95/08/30 ORIGIN : FLIC TAPE NAME : 9523[ CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., KUPARUK 2T-28, API #50-103-20225-00 TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA 2T-28 501032022590 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 39-AUG-95 BIT RUN 1 BIT RUN 2 BIT RUN 3 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 9) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 95231 GREEN TRANTHAM 95231 GREEN TRANTHAM 1 liN 8E 597 556 122.99 122.99 89.79 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 8.599 9.875 4274.9 PAGE: ~_IS Tape Verification Listing Schlumberger Alaska Computing Center 30-AUG-1995 16:14 3RD STRING PRODUCTION STRING REMARKS: Well drilled 2g-JUN through 3-JUL-g5 with CDR only. All data was collected in two bit runs, $ $ **** FILE HEADER FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 95/08/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : PAGE: FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENt: ~.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH CDR 5092.0 10882.0 $ BASELINE CURVE FOR SHIFTS: GRCH.USIT CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GR.MWD 88888.0 88850 10655.0 le647 106~7.5 10599 10597.~ 10589 10543.~ 10534 10483.~ 10474 10461.~ 1~454 10435.5 10426 10359.0 10350 10332.~ 10322 10215.~ 10205 10179.5 10171 10156.5 10146 10137.0 10128 10124.0 10115 10~$4.5 10074 10052.0 1~041 10~28.5 10019 10e17.5 10007 .5 .5 .5 .5 .5 .5 .0 5 0 5 5 0 5 0 5 5 0 5 5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-AUG-1995 16:14 10e05.5 9997.0 9982.0 9973.0 9894.5 9886.5 9872.5 9865.0 9866.5 9857.5 9838.0 9829.0 9832.5 9823.0 9806.5 9798.5 9754.0 9744.5 9747.5 9737.5 9734.5 9726.0 9694.0 9684.5 9682.0 9671.0 9665.0 9656.0 9649.5 9641.0 9631.0 9623.5 9619.e 9610.5 9614.5 9606.5 9558.0 9549.5 9516.0 9507.0 9479.5 9471.5 9474.0 9465.0 9426.5 9418.0 9387.e 9378.0 9379.0 9370.5 9361.5 9352.0 9354.5 9346.~ 9300.0 9291.5 9293.5 9286.~ 1~0.0 92.5 $ MERGED DATA SOURCE LDWG TOOL CODE BIT RUN NO. MERGE TOP MERGE BASE CDR 1 5092.0 5525.0 CDR 2 5530.0 1~882.0 $ REMARKS: The depth adjustments shown above reflect the MWD GR to the USIT GR logged by SWS. All other MWI) curves were carried with the GR. This file also contains the Very Enhanced ~RO resisitivity with 2' average that was reprocessed at GeoQuest. Upper transmitter failure during Run ~2. See raw files for further remarks. $ # LIS FORMAT DATA PAGE: LIS Tape Verification List|rig Schlumberger Alaska Computing Center 30-AUG-1995 16:14 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB *, TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 40 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 25 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 0 PAGE: SET TYPE - CHAN ** NAME SERV UNIT SERVICE API AP1 AP1 API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOQ TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 57033 90 999 ~9 9 1 1 I 4 68 9900090090 RA MWD OHMM 57033 99 ~09 09 9 1 1 1 4 68 00~0990090 RP MWD OHMM 57033 9~ 90~ 00 9 1 1 1 4 68 00~90~9~9 VRA MWD OHMM 57033 0~ 990 00 0 1 1 1 4 68 9000090090 VRP MWD OHMM 57033 90 990 09 0 1 1 1 4 68 0009000~00 DER MWD OHMM 57033 99 009 09 9 1 1 1 4 68 0090090099 ROP MWD FPHR 57033 0~ ~90 ~0 9 1 1 1 4 68 0000000000 FET MWD HR 57933 9~ ~0~ 09 0 1 1 1 4 68 09900~0090 GE MWD GAPI 57~33 90 990 00 0 1 1 1 4 68 0000009009 GRCH USIT GAPI 57e33 9~ 909 ~0 9 1 1 1 4 68 0990000099 ** DATA ** DEPT. 10882.5~9 RA.MWD -999.250 RP.MWD VRP.MWD -999.259 DER.MWD -999.250 ROP.MWD GR.MWD -999.259 GRCH.USIT -999.250 DEPT. 5096.599 RA.MWD 23.632 RP.MWD VRP.MWD 48.976 DER.MWD 98.683 ROP.MWD GR.MV~) 24.331 GRCH.USIT -999.259 -999.250 VRA.MWD 38.873 FET.MWD 116.738 VRA.MWD 892.2~4 FET.MWD -999.259 -999.250 26.025 0.458 ** END OF DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center **** FILE TRAILER FILE NAME : EDIT .OO~ SERVICE : FLIC VERSION : ~lC~i DATE : 95/08/39 MAX REC SIZE : 1924 FILE TYPE : LO LAST FILE : **** FILE HEADER FILE NAME : EDIT SERVICE : FLIC VERSION : 991C91 DATE : 95/98/$9 MAX REC SIZE : 1924 FILE TYPE : LO LAST FILE : 39-AUG-1995 [6:[4 PAGE: FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: 9.5999 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH CDR $ MERGED DATA SOURCE LDWG TOOL CODE 4699.9 5992.9 MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE MAD $ REMARKS: LIS FORMAT DATA 1 i 4699.9 5992.9 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-AUG-1995 16:~4 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB., TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 ~ 66 1 SET TYPE - CHAN ** PAGE: 6 NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER ~ LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 57~33 0~ ~00 00 0 2 1 1 4 RA MAD OHMM 57033 00 000 00 0 2 1 1 4 RP MAD OHMM 57033 00 000 00 0 2 I 1 4 VRA MAD OHMM 57033 00 000 00 9 2 ! 1 4 VRP MAD OHMM 57033 00 ~90 00 9 2 1 1 4 DER MAD OHMM 57933 0~ e99 99 9 2 1 1 4 ROP MAD FPHR 57933 09 099 09 0 2 1 1 4 FET MAD HR 57933 0~ 909 09 0 2 1 1 4 GR MAD GAPI 57933 0~ 990 09 9 2 1 1 4 DATA DEPT. 5096.59~ RA.MAD 23.632 RP.MAD VRP.MAD 48.916 DER.MAD 98.683 ROP.MAD GR.MAD 24.331 DEPT. 4596.~0~ RA.MAD VRP.MAD -999.259 DER.MAD GR.MAD 82,538 -999.259 RP.MAD -999.250 ROP.MAD 116,138 VRA.MAD 892.204 FET.MAD -999.259 VRA.MAD -999.259 FET.MAD 26.925 9.458 -999.250 -999.259 END OF DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center ***, FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 901C01 DATE : 95/98/39 MAX REC SIZE : 1924 FILE TYPE : LO LAST FILE : 39-AUG-1995 16:14 PAGE: **** FILE HEADER FILE NAME : EDIT .993 SERVICE : FLIC VERSION : 991C91 DATE : 95/98/39 MAX REC SIZE : 1924 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED MAD PASSES Depth shifted and clipped curves; for each pass of each run in separate files. MAD RUN NUMBER: 1 MAD PASS NUMBER: 1 DEPTH INCREMENT: 9.5999 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH CDR 4699.9 5992.9 $ BASELINE CURVE FOR SHIFTS: GRCH,USIT CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GR,MAD 88888.9 88889.5 5194.0 5~96.5 190.9 92.5 $ REMARKS: MAD DATA BLOCK SHIFTED -7.5' (SAME AS TOP OF MW[) DATA) $ LIS FORMAT DATA LIS Tape Verification L;st|ng Schlumberger Alaska Comput;ng Center 30-AUG-1995 16:14 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 I SET TYPE - CHAN ** PAGE: 8 NAME SERV UNIT SERVICE AP1 AP1 API AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 57033 ee 00~ 00 0 3 I I 4 RA MAD OHMM 57033 eO 00~ 00 0 3 1 1 4 RP MAD OHMM 57033 ~0 Oe~ Oe 0 3 ! i 4 VRA MAD OHMM 57033 ~0 e00 ~0 0 3 1 1 4 VRP MAD OHMM 57033 00 000 00 0 3 1 1 4 DER MAD OHMM 57033 00 000 e~ 0 3 I 1 4 ROP MAD FPHR 57033 00 0~0 00 ~ 3 1 1 4 FET MAD HR 57033 00 O~e. ~0 0 3 1 1 4 GE MAD GAPI 57033 ~ ~0 ~0 ~ 3 1 1 4 DATA DEPT, 5096,500 RA,MAD 23,632 RP,MAD VRP,MAD 48,916 DER,MAD 98,683 ROP,MAD GR,MAD 24,331 116.138 VRA,MAD 892,204 FET,MAD 26,025 0,458 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Comput|ng Center **** FILE TRAILER ****' FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 001C01 DATE : 95/08/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : *~** FILE HEADER FILE NAME : EDIT .004 SERVICE : FLIC VERSION : DATE : 95/08/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 30-AUG-lMM5 16:14 PAGE: FILE HEADER FILE NUMBER 4 RAW MWD Curves and log header data for each bit run in .separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CDR $ LOG HEADER DATA 5092.0 5525.0 DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 4-AUG-95 FAST2.5/20.4 V4.0C MEMORY le794.~ 4607.~ 10794.0 TOOL NUMBER CDR $ RESISTIVITY/GAMMA RAY RGS051 LIS Tape Veri~ica%Jon L|s%ing Schlumberger Alaska Compu%ing Cen%er 30-AUG-1995 16:14 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): 8.500 4274.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C$): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): SEAWATER 8.50 2.300 72.0 1.950 69.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: **************** BIT RUN #1 ******************** RES TO BIT: 65.5'; GR TO BIT: 75.92~ Well drilled ~rom 51~6~ %0 56~1' Mad pass da%a collec%ed ~rom 4671' %0 5106~ $ # LIS FORMAT DATA PAGE: 10 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT LIS Tape Verifica%ion Lis%ing Schlumberger Alaska Compu%ing ten%er 30-AUG-Ig9~ 16:14 PAGE: TYPE REPR CODE VALUE 15 66 68 16 66 l 0 66 1 SET TYPE - CHAN ,= NAME SERV UNIT SERVICE AP1 AP1 API AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 57033 eO 000 00 0 4 I 1 4 68 0000000e00 ATR LW1 OHMM 57033 0~ 0e0 00 0 4 1 1 4 68 0000000e00 PSR LW1 OHMM 57033 ~0 000 ~0 0 4 1 1 4 68 0000000000 DER LW1 OHMM 57033 00 0e0 00 0 4 ~ 1 4 68 000000eooe ROPE LWI F/HR 57033 00 0e0 eO 0 4 I I 4 68 eeeeeeeeee TAB LW1 HR 57033 00 000 00 0 4 1 1 4 68 0000000000 GR LW1 GAPI 57033 00 000 00 0 4 1 1 4 68 0000000000 ** DATA DEPT. 5599.~00 ATR.LWl -999.25e PSR.LW[ -999.250 DER.LW1 ROPE.LW1 409.542 TAB.LW1 -999.250 GR.LWl -999.250 DEPT. 5104.000 ATR.LW1 23.632 PSR.LW1 116.138 DER.LW1 ROPE.LW1 892.204 TAB.LW1 0.458 GR.LW1 24.331 -999.250 98.683 END OF DATA **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : ~1C~1 DATE : 95/08/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER FILE NAME : EDIT .005 SERVICE : FLIC VERSION : 001C01 DATE : 95/08/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-AUG-1995 16:14 FILE HEADER FILE NUMBER 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CDR 5530.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 10882.0 4-AUG-95 FAST2.5/20.4 V4.BC MEMORY le794.0 4607.0 1~794.0 TOOL NUMBER CDR $ RESISTIVITY/GAMMA RAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (CS): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON T00L MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): RGS051 8.500 4274.0 SEAWATER 8.50 2.300 1.95~ 72.0 69.0 PAGE: 12 LIS Tape Verification Listing Schlumberger Alaska Computing Center 30-AUG-1995 16:14 TOOL 'STANDOFF (TN): EWR FREO, UENCY (HZ): REMARKS: **************** B~T RUN #2 ******************** RES TO BIT: 65.5'; GR TO BIT: 75.92' Well drilled from 5601' to 10890'. Note: Upper transmitter failed intermittantly for Run2. Log presented is computed from lower transmitter only. Separate log presented of borehole corrected original data over Kuparuk zone for comparison. Run 1 data is all borehole corrected data. ATVR & PSVR should be used with caution over Run #2. Well TD'd at 11:45 on 2-JUL-95. Hole deviation at TD= 40.85 deg. $ LIS FORMAT DATA PAGE: 13 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 APl AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 57033 90 999 99 9 5 1 1 4 68 9999999999 ATR LW2 OHMM 57933 99 999 99 9 5 1 1 4 68 9999999999 PSR LW2 OHMM 57933 99 999 99 9 5 1 I 4 68 9999999990 DER LW2 OHMM 57933 99 999 99 9 5 1 1 4 68 9990999999 ROPE LW2 F/HR 57033 90 990 99 9 5 1 1 4 68 9990999099 · LIS Tape Verii~ication Listing Schlumberger Alaska Computing Center 30-AUG-1995 16:14 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TAB LW2 HR 57033 00 000 00 0 5 1 1 4 68 0~0090~000 GR LW2 GAPI 57935 99 999 99 0 5 1 1 4 68 999000~909 ** DATA ,= DEPT. ~9586.999 ATR.LW2 -999.25e PSR.LW2 -999.259 DER.LW2 ROPE.LW2 $6.[45 TAB.LW2 -999.250 GR.LW2 -999.259 DEPT. 5526.599 ATR.LW2 -999.250 PSR.LW2 -999.259 DER.LW2 ROPE.LW2 -999.259 TAB.LW2 -999.250 GR.LW2 88.979 -999.259 -999.259 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .~e5 SERVICE .: FLIC VERSION : 091C91 DATE : 95/95/39 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .996 SERVICE : FLIC VERSION : 991c9~ DATE : 95/98/39 MAX REC SIZE : 1924 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RAW MAD Curves and log header data for each pass of each run in separate files. MAD RUN NUMBER: MAD Pass NUMBER: DEPTH INCREMENT: 0.5~90 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH LIS Tape Verifica%ion Lis%ing Schlumberger Alaska Compu%ing Cen%er SO-AUG-1995 16:14 PAGE: 15 CDR $ LOG HEADER DATA 4600.0 DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 5092.0 4-AUG-95 FAST2.5/2e.4 V4.0C MEMORY 10794.0 4607.0 10794.0 TOOL NUMBER CDR $ RESISTIVITY/GAMMA RAY RGS051 BOREHOLE AND CASING DATA OPEN HOLE. BIT SIZE (IN): DRILLERS CASING DEPTH (FT): 8.500 4274.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): SEAWATER 8.5~ 2.3~0 1.950 72.0 69.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: **************** BIT RUN #1 ******************** RES TO BIT: 65.5'; GR TO BIT: 75.92'. Well drilled from 51~6' %0 5601' Mad pass da%a collec%ed from 4671' %0 5106' $ LIS FORMAT DATA LIS Tape Veri~|caf~ion Lis~,ing Schlumberger Alaska Comput;ing Cent, er 30-AUG-1995 16:14 PAGE: DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 36 12 68 13 66 14 65 FT 15 66 68 16 66 0 66 SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 57033 00 ~0~ ~ 0 6 1 1 4 ATR MA1 OHMM 57033 0~ 000 00 0 6 1 1 4 PSR MA1 OHMM 57033 00 00~ 00 0 6 1 1 4 DER MA1 OHMM 57033 00 000 00 0 6 1 1 4 ROPE MA1 F/HR 57033 00 00~ ~0 ~ 6 1 1 4 TAB MA1 HR 57033 00 00e ~0 0 6 1 1 4 GR MA1 GAPI 57e33 00 00e eO e 6 1 1 4 ** DATA ** DEPT. 5104.000 ATR.MA1 23.632 PSR.MA1 ROPE.MA1 892.204 TAB.MA1 0.458 GR.MA1 DEPT. 4596.0e0 ATR.MA1 -999.250 PSR.MA1 ROPE.MA1 -999.250 TAB.MA1 -999.250 GR.MA1 116.138 DER.MA1 24.331 -999.250 DER.MA1 96.105 98.683 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger A~aska Comput|ng Center 30-AUG-1995 16:14 PAGE: 17 · .** FILE TRAILER ..-. FILE NAME : EDIT .006 SERVICE : FLIC VERSION : eeicei DATE : 95105/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER SERVICE NAME : EDIT DATE : 95/08/30 ORIGIN : FLIC TAPE NAME : 95231 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., KUPARUK 2T-28, API #50-103-20225-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 95/e8/30 ORIGIN : FLIC REEL NAME .: 95231 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., KUPARUK 2T-28, API #50-103-20225-00