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Home My WebLink About196-118Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 10/27/2025 InspectNo:susKPS250920194002 Well Pressures (psi): Date Inspected:9/20/2025 Inspector:Kam StJohn If Verified, How?Other (specify in comments) Suspension Date:8/8/1997 Tubing: IA: OA: Operator:ConocoPhillips Alaska, Inc. Operator Rep:Bruce Richwine Date AOGCC Notified:9/18/2025 Type of Inspection:Subsequent Well Name:KUPARUK RIV UNIT 3G-25 Permit Number:1961180 Wellhead Condition N/A Surrounding Surface Condition Clean gravel, no sign of any sheen Condition of Cellar N/A Comments This well head has been cut off and marker plate installed but was only buried 2 ft below pad grade. Location was located with 3G pad plot map Supervisor Comments Photos (2) attached Suspension Approval:Completion Report Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Monday, October 27, 2025          2025-0920_Suspend_KRU_3G-25_photos_ksj Page 1 of 1 Suspended Well Inspection – KRU 3G-25 PTD 1961180 AOGCC Inspection Rpt # susKPS250920194002 Photos by AOGCC Inspector K. StJohn 9/20/2025 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 3725'feet Surface, 210', 3070', 3230' feet true vertical 3069' feet None feet Effective Depth measured 47'feet N/A feet true vertical 47' feet N/A feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) N/A Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk River Oil Pool- SUSPENDED 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A N/A Dusty Freeborn Dusty.Freeborn@conocophillips.com 907-659-7224Staff Well Integrity Engineer 3065-3067' 2588-2589' measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 121' ~~~ SUSPENDED ~~ ~ measured TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 196-118 50-103-20244-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL025547 Kuparuk River Field/ Kuparuk River Oil Pool KRU 3G-25 Plugs Junk measured Length Production Liner Casing 3715' 121'Conductor Surface Intermediate 16" 7-5/8" 79' 3800' 3064' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 10:03 am, Sep 26, 2025 Digitally signed by Dusty Freeborn DN: CN=Dusty Freeborn, O=ConocoPhillips Alaska, OU= Well Integrity and Intervention, E=Dusty.Freeborn@ conocophillips.com, C=US Reason: I am the author of this document Location: Anchorage, Alaska Date: 2025.09.24 11:14:33-08'00' Foxit PDF Editor Version: 13.1.6 Dusty Freeborn J.Lau 11/5/25 RBDMS JSB 100225 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 12, 2025 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Suspended Well Inspection 10-404 Sundry Kuparuk River Unit 3G-25 (PTD 196-118) Commissioner Chmielowski: Enclosed please find the quinquennial suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc.Kuparuk River Unit 3G-25 (PTD 196-118). The following documents are attached: - 10-404 Sundry - Suspended Well Check List - Wellbore Schematic - Location Plot Plan - Photographs Please call me on (907) 265-6218 if you have any questions. Sincerely, Dusty Freeborn Well Integrity Engineer ConocoPhillips Alaska, Inc. Digitally signed by Dusty Freeborn DN: CN=Dusty Freeborn, O=ConocoPhillips Alaska, OU =Well Integrity and Intervention, E=Dusty.Freeborn@ conocophillips.com, C=US Reason: I am the author of this document Location: Anchorage, Alaska Date: 2025.09.24 11:15:07-08'00' Foxit PDF Editor Version: 13.1.6 Dusty Freeborn “Copyright 2025. All rights reserved. This photograph is provided to the AOGCC with permission to copy for its own use. Copying for any other purpose or by any other party is prohibited without the express consent of ConocoPhillips Alaska, Inc.” “Copyright 2025. All rights reserved. This photograph is provided to the AOGCC with permission to copy for its own use. Copying for any other purpose or by any other party is prohibited without the express consent ofConocoPhillips Alaska, Inc.”“Copyright 2025. All rights reserved. This photograph is provided to the AOGCC with permission to copy for its own use. Copying for any other purpose or by any other party is prohibited without the express consent of ConocoPhillips Alaska, Inc.” 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.W ell Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): Casing Collapse Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.W ell Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15.W ell 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: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: Perforation Depth MD (ft): TVD BurstMDLength Size Perforation Depth TVD (ft): Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft): approval: Notify Commission so that a representative may witness Sundry Number: BOP TestMechanical Integrity Test Location Clearanc e ection MIT Req'd? Yes No ption Required? Yes No Subsequent Form Required: COMMISSION USE ONLY Contact Name: Contact Email: Contact Phone: Date: e: certify that the foregoing is true and the procedure approved herein will not rom without prior written approval. gnature: me: Date for 15.W ell Status after proposed work: Operations:OILWINJ W DSPL Suspended proval:Date:GASWAGGSTOR SPLUG Representative:GINJ Op Shutdown Abandoned nts: Proposal Summary Wellbore schematic13.W ell Class after proposed work: ations Program BOP SketchExploratory Stratigraphic Development Service quest: Abandon Plug Perforations Fracture Stimulate Repair We Operations shutdownpair Well Suspend Perforate Other Stimulate Pull Tub Change Approved Programll Tubing Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___er Casing ________________ __ ame:4.Current Well Class:5.Permit to Drill Number: Exploratory Development Stratigraphic Service 6.API Number: g:8.W ell Name and Number: ation or Conservation Order governs well spacing in this pool? perforations require a spacing exception?Yes No esignation (Lease Number):10.Field/Pool(s): D (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): g Collapse SSSV Type:Packers and SSSV MD (ft) and TVD (ft): pth MD (ft): TVD BurstMDLengthSize Perforation Depth TVD (ft):Tubing Size: PRESENT WELL CONDITION SUMMARY Tubing Grade:Tubing MD (ft): Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 196-118 50-103-20244-00-00 n/a KRU 3G-25 ADL 25547 Kuparuk River Field/Kuparuk River Oil Pool 3725 3069 56 56 2110, 3040, 3070 n/a Conductor 121' 16" 121 121 Surface 3715' 7-5/8" 3715 3062 3065-3067 2588-2589 n/a n/a n/a n/a n/a 08/08/1997 Stephanie Pilch Well Integrity & Compliance Specialist Digitally signed by Stephanie Pilch DN: C=US, O=CPAI, CN=Stephanie Pilch, E=stephanie.r.pilch@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-10-10 07:57:12 Foxit PhantomPDF Version: 10.0.0 Stephanie Pilch 10/10/20 Stephanie Pilch/Sara Carlisle n2549@conocophillips.com (907)659-7126 ✔Suspension Renewal ✔ ✔ ✔✔ ✔ By Samantha Carlisle at 6:09 pm, Oct 11, 2020 320-432 VTL 11/02/20 NA NONE X DSR-10/12/2020DLB10/12/2020 X Comm. 11/2/2020 dts 11/2/2020 JLC 11/2/2020 RBDMS HEW 11/12/2020 !"##$ %& %' ( )* "(%+)$,-./ #0) 12 -(34, -3256'' ('"(%+)$,-./ #0) 12( $4 4. 5(75 0 )* *4. ' )* '4 -'!& ).5(!!6! '!''-8!4 ).'-8!('''9('4 ).(4 -36'(!' -8(''9('4 - 0$#) 0'5564 5 (- -( 3!58 ( ( Digitally signed by Stephanie Pilch DN: C=US, O=CPAI, CN=Stephanie Pilch, E=stephanie.r.pilch@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-10-10 07:57:30 Foxit PhantomPDF Version: 10.0.0 Stephanie Pilch !""# $% &'& ())* !&$ + ( #,-./"0(12 3&4 5 5 & & 5 6* #74 - &'7!&$ + ( #,-./"0(127 .4 % (())* (& 8 (6 (8 -- (- & . 6 4-96&44 :& 47 - 0#"( 0 4**5 7 * & - - & ' *9 & & Digitally signed by Stephanie Pilch DN: C=US, O=CPAI, CN=Stephanie Pilch, E=stephanie.r.pilch@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-06-10 15:22:05 Foxit PhantomPDF Version: 9.7.0 Stephanie Pilch 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 Other: ______________________ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured feet feet true vertical feet feet Effective Depth measured feet feet true vertical feet feet Perforation depth Measured depth feet True Vertical depth feet Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 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: Contact Phone: 2. Operator Name: Senior Pet. Engineer: Senior Res. Engineer: CollapseBurstTVDLengthCasing Authorized Signature with date: Authorized Name: 5. Permit to Drill Number: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf measuredPlugs Junk measured STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 3. Address: 4. Well Class Before Work: Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureOil-Bbl measured true vertical Packer WINJ WAG Water-Bbl MD Form 10-404 Revised 3/2020 Submit Within 30 days of Operations ConocoPhillips Alaska, Inc PO Box 100360 Anchorage, AK 99510 196-118 50-103-20244-00-00 ADL 25547 KRU 3G-25 N/A Kuparuk River Field/Kuparuk River Oil Pool 3725 3069 2110, 3040, 3070 N/A 56 56 N/A N/A Conductor 121' 16" 121 121 Surface 3715' 7-5/8" 3715 3062 3065-3067 2588-2589 N/A N/A N/A N/A N/A Stephanie Pilch Well Integrity & Compliance Specialist Stephanie Pilch/Sara Carlisle n2549@conocophillips.com (907) 659-7126 Suspended well inspect ✔ ✔ ✔✔ ✔ Digitally signed by Stephanie Pilch DN: C=US, O=CPAI, CN=Stephanie Pilch, E=stephanie.r.pilch@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-06-10 15:21:48 Foxit PhantomPDF Version: 9.7.0 Stephanie Pilch 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 Other: ______________________ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured feet feet true vertical feet feet Effective Depth measured feet feet true vertical feet feet Perforation depth Measured depth feet True Vertical depth feet Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 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: Contact Phone: 2. Operator Name: Senior Pet. Engineer: Senior Res. Engineer: CollapseBurstTVDLengthCasing Authorized Signature with date: Authorized Name: 5. Permit to Drill Number: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf measuredPlugs Junk measured STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 3. Address: 4. Well Class Before Work: Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureOil-Bbl measured true vertical Packer WINJ WAG Water-Bbl MD 15. Well Class after work: Exploratory Development Service Stratigraphic 16. Well Status after work: Oil Gas W DSPL a GSTOR GINJ SUSP SPLUG 5.070, 25.071, & 25.283) J G Plug Perforations Fracture Stimulate Pull TubingOperations shutdown Perforate Other Stimulate Alter Casing Change Approved Program Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ Development Exploratory StratigraphicService 6. API Number: mber): 8. Well Name and Number: onic data per 20AAC25.071): 10. Field/Pool(s): ry: ured feet feet ticalfeet feet ured feet feet ticalfeet feet epth feet epth feet true vertical depth) d and true vertical depth) summary: lumes used and final pressure: tion: ion: CollapseBurstTVD 5. Permit to Drill Number: Size Gas-Mcf g Ju easu ed 4. W ell Class Before W ork: Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureOil-Bbl ue e ca W ater-Bbl MD Form 10-404 Revised 3/2020 Submit Within 30 days of Operations ConocoPhillips Alaska, Inc PO Box 100360 Anchorage, AK 99510 196-118 50-103-20244-00-00 ADL 25547 KRU 3G-25 N/A Kuparuk River Field/Kuparuk River Oil Pool 3725 3069 2110, 3040, 3070 N/A 56 56 N/A N/A Conductor 121' 16" 121 121 Surface 3715' 7-5/8" 3715 3062 3065-3067 2588-2589 N/A N/A N/A N/A N/A Stephanie Pilch Well Integrity & Compliance Specialist Stephanie Pilch/Sara Carlisle n2549@conocophillips.com (907) 659-7126 Suspended well inspect ✔ ✔ ✔✔ ✔ Digitally signed by Stephanie Pilch DN: C=US, O=CPAI, CN=Stephanie Pilch, E=stephanie.r.pilch@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-06-10 15:21:48 Foxit PhantomPDF Version: 9.7.0 Stephanie Pilch By Samantha Carlisle at 3:33 pm, Jun 10, 2020 DSR-6/11/2020 RBDMS HEW 6/11/2020 VTL 7/27/20 3725 SFD 6/11/2020 !""# $% &'& ())* !&$ + ( #,-./"0(12 3&4 5 5 & & 5 6* #74 - &'7!&$ + ( #,-./"0(127 .4 % (())* (& 8 (6 (8 -- (- & . 6 4-96&44 :& 47 - 0#"( 0 4**5 7 * & - - & ' *9 & & Digitally signed by Stephanie Pilch DN: C=US, O=CPAI, CN=Stephanie Pilch, E=stephanie.r.pilch@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-06-10 15:22:05 Foxit PhantomPDF Version: 9.7.0 Stephanie Pilch STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed Suspend E Perforate r Other Stimulate r Alter Casing r Change Approved Program E Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other.Suspended well inspect 2 Operator Name: 4.Well Class Before Work 5 Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 196-118 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-103-20244-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25547 K'Q.0 3G-25 9 Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Kuparuk River Field/Kuparuk River Oil Pool 11 Present Well Condition Summary: Bridge Plug 2110' Total Depth measured 3725 feet Plugs(measured) Cement retainer 3040' Bridge Plug 3070' true vertical 3069 feet Junk(measured) None Effective Depth measured 56 feet Packer(measured) 0 true vertical 56 feet (true vertical) 0 Casing Length Size MD TVD Burst Collapse CONDUCTOR 121 16 121' 121 1640 630 SURFACE 3715 7.625 3715' 3062 6890 4790 RECEIVED Perforation depth. Measured depth: 3065-3067 1'.,l . /'i � JUN 30 2015 True Vertical Depth: 2588-2589 AOGCC AOGCC Tubing(size,grade,MD,and TVD) None Packers&SSSV(type,MD,and TVD) None 12.Stimulation or cement squeeze summary: NA Intervals treated(measured). Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA _ NA NA NA - NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25 070,25.071,&25 283) 15 Well Class after work: Daily Report of Well Operations r Exploratory r Development Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP F SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C O Exempt NA Contact MJ Loveland/Martin Walters Email N1878@cop.com Printed Name MJ Loveland Title Well Integrity Project Supervisor Signature /1/7-76/2/7- Phone 659-7043 Date �� /�_ /l 5 ,A4.' r f RBDMSJ S JUL - 1 2015 Form 10-404 Revised 5/2015 Submit Original Only y' • • RECEIVED ConocoPhillips JUN 3 0 2015 Alaska P.O. BOX 100360 AO G G C ANCHORAGE,ALASKA 99510-0360 June 29, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Suspended Well Inspection 10-404 Sundry Kuparuk River Unit 3G-25 (PTD 196-118) Dear Commissioner Foerster: Enclosed please find the quinquennial suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. Kuparuk River Unit well 3G-25 (PTD 196-118). The following documents are attached: - 10-404 Sundry - Suspended Well Check List - Wellbore Schematic - Location Plot Plan - Photographs The well is being held until a formal P&A can be completed at the end of field/pad life. Please call Martin Walters or me at 659-7043 if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: KUPARUK RIV UNIT 3G-25 Field/Pool: KUPARUK RIVER Permit#(PTD): 196-118 API Number: 50-103-20244-00-00 Operator: ConocoPhillips Alaska, Inc. Date Suspended: 8/11/1997 Surface Location: 2538' FNL, 20' FWL Section: 24 Township: 12N Range: 8E Nearest active pad or road: KRU DS3G Meridian: UMIAT Take to Location Digital camera Map showing well location/Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Clean /Good Pad or location surface: good Location cleanup needed: NA Pits condition: NA Surrounding area condition: good Water/fluids on pad: None Discoloration, Sheens on pad, pits or water: NA Samples taken: NA Access road condition: Good Photographs taken (#and description): 2 photos of area Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2)well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: NA-Well head cut off below grade Cellar description, condition, fluids: NA Rat Hole: NA Wellhouse or protective barriers: NA Well identification sign: NA Tubing Pressure (or casing if no tubing): NA Annulus pressures: NA Wellhead Photos taken (#and description): none Work Required: None Operator Rep (name and signature): Perry Greenwood AOGCC Inspector: Johnnie Hill Other Observers: MJ Loveland Inspection Date: 6/27/2015 AOGCC Notice Date: 6/25/2015 Time of arrival: 1300 Time of Departure: 1305 Site access method: truck KUPARUK RIVER UNIT WELL 3G-25 P&A Plan ' Casing cut 4 base of cellar ''J (±2' below pad grade) ;... ±158 s.; '•ti •: of AS '•' �J'•'' and dry hole marker put on !< :ylj,, to 6'below 16" Conductor to 121' ground level Yj;'' ;�;SrCemented to Surface �. : I (Top @ 52'MD) ;tr;• bridge plug ® 210' MD Top job w/12 bbl ASIII 10.0 ppg mud and water spacer 4771.0 10.0 ppg - Top of ASIII from squeeze calculated Original ground level = 47.3' : t ,;• mud ••;:, @ 845'w/guage hole above MSL Pad level =52.6' above MSL Parker 245 rig RKB = 41.5' • a: "','•' `'`•�'`' 75'ofASI Baker K-1 cement retainer :til. ;;�J:: .;�;r%::. :•;:r @ 3040'(on drillplpe) :' Tested to 20KIbs&2000 psi ;�1•,': �ti'�;' 7/29/98 ;:t. ::;, Perfs from 3067-3065', 9 holes 10.0dP9 mud Squeezedbbl w/90.7 bbl ASIII&42.1 J.: : .,J '41S: tr Baker N-1 drillable • —�— • f • Top of Class G estimated bridge plug @ 3070'(on Eline) i— CO 3230'based on CBT log Tested to 2000 psi 7/27/96 10.0 ppg mud 7-5/8",29.7#, L80 Shoe @ 3715' Cemented with 770 sx AS 111 TD 3725' and 300 sx Class G in primary job ALL DEPTHS ARE MEASURED DEPTHS - PARKER 245 RKB - 41.5'. 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''',,,:.„''',1,1).),'':.'-'2::;'::::'-:'''em ' s-..*'i''::- ' ' °1 it'''''' . -1„:2.3;t ''` a. i a ,"l..x q x '' ___------lw--- or ,, ,_,..,...„. .,;,,,,_,,,,, ,,,A,;,,,, *„.,,_ ,-.'- ,- ti , #,',.',%.., ° � e✓+r«'..".� w �r " 5 ':1'....'':":.‘:.'..'...'..,:'..7';'7...‘.''.,", � ',,,,,,,o,\;,,,,‘,,,,, I $ Y� Yin i..4 y ,• ' r STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 06/27/15 Inspector: Johnnie Hill Operator: ConocoPhillips Alaska Inc Well Name: KRU 3G-25 - Oper.Rep: Perry Greenwood PTD No.: 196-118 Oper.Phone: Location Verified? Yes Oper. Email: If Verified,How? Other(specify in comments) Onshore/Offshore: Onshore Suspension Date: 08/11/97 Date AOGCC Notified: 06/25/15 ' Sundry No.: Well Completion Report • Type of Inspection: Subsequent - Wellbore Diagram Avail.? No Well Pressures(psi): Tubing 0 . Photos Taken? No IA 0 OA 0 ED r 1 9 ))rl Condition of SCANtl .AUU LO15 Wellhead: cut off below surface Condition of Surrounding Surface Location: good gravel Follow Up Actions Needed: none Comments: well was verified by pad well location map Attachments: None REVIEWED BY: Insp.Supry Comm PLB 06/2014 2015-0627_Suspend_KRU_3G-25jh.xlsx • • SIRE EF AELASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COM1'IISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 'q Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3G -25 Sundry Number: 310 -421 M`h 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, 41P / Daniel T. eamount, Jr. Chair DATED thiss. day of January, 2011. Encl. S • 11111V . . Conoco Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 RECEIVED DEC 1 4 2010 December 11, 2010 ti Oil & Gas Cons. Commission Commissioner Dan Seamount AnChorege Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Re: Renewal of Suspended Well 10 -403 Status Kuparuk River Unit 3G -25 (PTD 196 -118) Dear Commissioner Seamount: ConocoPhillips Alaska Inc. (CPAI) hereby submits a request for renewal of the suspension status of Kuparuk River Unit well 3G-25 (PTD 196 -118) per 20 AAC 25.110. The well was visually inspected September 29, 2010 and the results submitted on a 10- 404. The condition of the well is noted on an attached schematic and 10 -403 form. Please note the following: - The well has been technically plugged and abandoned but requires the casing to be cut farther below grade before a formal P &A status can be granted. - The final P &A casing cut is planned for end of field/pad life. - The well is on an active pad. CPAI request the renewal of the suspension because the well is being held until a formal ,/ P &A can be completed at the end of field/pad life. Please call Perry Klein or me at 659 -7043 if you have any questions. Sincerely, �j� yr , / , r J Loveland ConocoPhillips Well Integrity Projects Supervisor . STATE OF ALASKA � ( ��t ALASKOL AND GAS CONSERVATION COMMISSIQN A 1 PPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 `' ,,� J 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair well r Change Approved Program r I"-• Suspend ` Plug Perforations r Perforate r Pull Tubing r Time Extension , 14' it Operational Shutdow n r Re -enter Susp. Well r Stimulate r Alter casing r Other: 51 `'. 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r • Exploratory r 196 -118 ' 3. Address: Stratgraphic r Service T 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20244 -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 3G -25 • 9. Property Designation: 10. Field / Pool(s): ADL 25547 ALK 2561 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): 3725 - 3069 . 56' 56' 210', 3040', 3070' 3627' Casing Length Size MD TVD Burst Collapse CONDUCTOR 121 16 121' 121' SURFACE 3715 7.625 3715' 3062' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3067 - 3065 - Cemented 2589 - 2588 - cemented None - - Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) NONE NONE 12. Attachments: Description Summary of Proposal J 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: _ NA Oil r Gas r WDSPL r Suspended rT f. //,� rN, 1 0 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland /Perry Klein Printed Name MJ Loveland /P ry Klein Title: WELL INTEGRITY SUPERVISOR Signature /07 -' Phone: 659 -7043 Date / - /,-/ Commission Use my Sundry Number: 3' O (4 0' Conditions of approval: Notify Commission so that a representative may witness ��lll "t Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r RECEIVED Other: L DEC 1 4 2010 NAtom_ � r Subsequent Form Required: " '`-"..-. 7 ( '--- 'ta5kla UH & Gas Cans. Commission Anchorage APPROVED BY / /51/ / Approved by: �� COMMISSIONER THE COMMISSION ?ate: BD SS AN 0 >61 01F- N / 3 /I t 1. (.° Form 10 -403 Revised X10 > R 1 G 1 A 1 Submit in Duplicate t' L,. / • • , . KUPARUK RIVER UNIT WELL 3G -25 P &A Plan Casing cut a base of cellar . , tiff, ti t tti ; ti t ti ti i ti ti 4 } � l . . IV ti t • ? } t } yr t and dry hole pad grade) ui + { ;',i ±168' of ASI ,{ rY p AV, s : to 6' below t . to 1 8 Conductor to 121' N t , 4. Vt ; ground level 4 Cemented to Surface . ;t ;; ; .. ; (Top 0 52' MD) 3�,t .. • tit tit }l m.i,l ,r N M, r. bridge plug ® 210' MD �• "�.- Top lob w/12 bbl ASIII 10.0 ppg mud and water spacer 5''c• 10.0 ppg ;,4 Top of ASIII from squeeze calculated Original ground level = 47.3' mud .. ® 845' w /guage hole above MSL ,tt, + Pad level = 52.6' above MSL i + y{ Parker 245 rig RKB = 41.5' t i .tttil tr tit {t ; ., t t t:t'r+ titttt {••{.: t t +t '141, i•••:•• 4. t.tit.tit.sl. +l.tit.Si•f r No. :{!tt 75' of ASI tt•.t{• : ,..k ` Baker K -1 cement retainer t" t : { '+t-4; 4. 0 3040' (on drillpipe) t.fa. _..1.,.� ti t Tested to 20Klbs & 2000 psi '`tfi ~ �� ' ,tz 7/29/96 ;rt ,, tit Perfs from 3067- 3065', 9 hoses isi 10.0 ppg wij Squeezed w/90.7 bbl ASIII & 42.1 ti tti mud .4.: bbl ASI Baker N -1 drillable ' � i - - � .• ; � -ter i Top of Class G estimated bridge plug 6 3070' (on Eline) I ® 3230' based on CBT log Tested to 2000 psi 7/27/96 I 10.0 ppg _. mud j [ , 7- 518 ",29.7 #, L80 S hoe Cs1 3715' Cemented with 770 sx AS III TD @ 3725' and 300 sx Class G in primary job ALL DEPTHS ARE MEASURED DEPTHS PARKER 245 RKB = 41.5'. DKP 3/97 ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/29/10 • Inspector: Bob Noble Operator: CPA Well Name: KRU 3G-25 Oper.Rep: Ian Ives PTD No.: 196-118 Oper.Phone: 659-7043 Location Verified? Yes Oper.Email: If Verified,How? ter(specify in commei Onshore/Offshore: Onshore Suspension Date: 08/08/97 Date AOGCC Notified: 08/28/10 Sundry No.: Well Completion Rpt Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing None Photos Taken? Yes IA None OA None Condition of Well location verfied with plot plat.There was no wellhead to be seen.CPA Rep. MJ Loveland told me that the well had been cut off Wellhead: 2'below ground level. Condition of Surrounding Surface The location had no sign of oil stains,just good clean gravel. Location: Follow Up Actions None Needed: �`�t414Ep AUG 0 3 2015 Attachments: None REVIEWED BY: Insp.Supry Comm PLB 08/2010 2010-0829_Suspend_KRU_3G-25_bn.xlsx • RECEIVED Frank Snyder Manager Onshore Exploration ConocoPhillips Alaska, Inc APR 0 3 2009 700 G Street, ATO 1476 Anchorage,AK 99510 ConocoPhillips Alaska Oil &Gas Cons.Commission (907)265-1138 (phone) (907) 236-4966 (fax) Anchor#pe Frank.C.Snyder@conocophillips.com April 1, 2009 SCANNED 0 C T 15 2014 Hand Deliveried Cathy Foerster Commissioner Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Subject: Notice of Revised Suspended Wells Regulations and Request for Verification of Suspended and Shut-In Well Information ConocoPhillips Alaska, Inc. (CPAI) is responding to the Alaska Oil and Gas Conservation Commission (AOGCC) letter date January 29, 2009 requesting CPAI to review the list of suspended, long term shut-in and observation wells operated by CPAI. CPAI has completed a detailed review of the suspended wells operated by CPAI. Attached is a list of CPAI suspended wells operated by CPAI. In summary CPAI added the following three wells to the list of CPAI operated suspended wells: Kuparuk River Unit 2F-20 Lisburne Exploration Tail — Wes} Gddt+,tl Lookout#1 West Sak 1-1=1-96A hii -icc' If you have any questions regarding Suspended Wells operated by CPAI, please contact me at 265-1138. Sincerely, Frank Snyder Manager Onshore plora 'on Attachment zz : � TTT � � � T (n ozc� c CCCCCCC c c c c cO = (v ' n n 0 x 0 0 0 a 0 a a a 0 a < 0 v :: 0 0 ��CCC v CD CU N v v v n) w N n) n> (D _ c <_ V) �t 'l . 1 1 1 1 -1 'Z -1 1 c 0 0 C c c c c c c c c c c c - ro 0 R4 01 `p C 0 7 7 1 �(7 73 A X X X 77 73 7J 70 ALJ 70 - eu - 0 (p Lf C < G G• < < G < R. R. < R. R. < cc =. ccccccc � � � v o c �a Qrt () (n (A (n 3 i N) — .0 ooD � W W N N N N N N Sll N N '* W co = G) mmm �(- x- � _ \''..'..'''' 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W r W W N1 I- .b.. r0 0) 0 CJS OD Co N N Ul 01 _A V ._A01 01 W ()l U1 - A N 0) CO Co C) --1 CO N N W N Co N W U7 .A Co V N 01 --• Co O .A k) _A o co 0) W co O co a .p (.0 " I.3 A Co Co Co o co - - - Ul V 00 -A CA CS) - - - r 0 7 V V V V V V V to O V V V o O O V O O O -. O o OW O O N N N V C .A W W N co .A CD N W (Ti co o a Co Co Co co co Co CO A V - V N CD V Co Co N CO - N V co Ui -• V i i i i i i i i a r- .p - .A -' .p (n 01 -' cn (r --' 01 S 0) Co Co .p V o .r, 01 01 Co w (D w w a) ao -' of c W a co U 01 CocoCo O CD W N 01 Co00 OD CO C" ~~I ~ THE MATERIAL UNDER THIS COVER HAS BEEN ~ICROFIL~ED O~ OR BEFORE JA~L~ARY 03,200~ R IS M C:LORl\MFn..M.DOC ) ) AOGCC Geological Materials Inventory 'ÞßRrJli~/ 96-118 ARca Log Data Sent Recieved Box CBL ~520 9/1 1/96 9/25/96 DIR SRVY ~UM 121-3725 9/4/97 9/5/97 t..-oI'((.4~7 Completion Date t/£/'.7. Daily well ops Ilf q /9.7 Are dry ditch samples required? yes -r~~:.1 no And received? l:~~=:: yes no.. Well is in compliance yes ~ñõ Analysis description recieved? yes 1~~eiVed? [:.:=--] ~Yes --- Itð' Was the well cored? Are tests required? Yes'- I I -no Initial Comments fìJ..Œ.. ~;~ili,--- _~__.~~__~~~.La___ -A.-ld.....- ~ 'i(c.j~ Ù ~ 9 .~\.~ ~ ~- r---- ~~-~ ~~ ~\\,- -I. ('('2\ IV \.. f;.1 \ 't'~. <:..1"-.... _' I.,':;;;' v... , L~ ~. [f!\ctct ~ I Monday, August 30, 1999 Page 1 of 1 ARca Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 \ } ') ~~ ~~ December 1, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RECEIVED DEC - 2 1997 Subject: 30-25 (Permit No. 96-118/397-58) Well Completion Report Alaska Oil & Gas Cons. Commission Anchorage Dear Mr. Commissioner: Enclosed is the corrected well completion form for KRU 3G-25. We have changed the status from abandoned to suspended. If there are any questions, please call 263-4183. Sincerely, ~~f~ D. K. Petrash Drilling Engineer Kuparuk Development ORIGINAL DKP/skad ) ) 1 Status of Well STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well OIL D GAS D SUSPENDED IKJ ABANDONED C]SERVICE D 2 Name of Operator ARCO Alaska, Inc 3 Address P.O. Box 100360, Anchorage, AK 99510-0360 4 Location of well at surface 7 Permit Number 96-118 & 397-58 8 API Number RECEIVED N/A At Total Depth , ,r' "''1(',",'" ' 'ohI:&- r~~W)i~~ '" .,"",',¡:"m" ","\I>, .",. I ·,H~J~.· ,¡ ¡¿ I~t<rl_ ' ',"''''~ ,i,!~~7;...:::-;,j 50-1 03-20244 9 Unit or Lease Name 2538' FNL, 20' FWL, Sec. 24, T12N, R8E, UM At Top Producing Interval Kuparuk River Unit 10 Well Number DEC - 2 199'7 3G-25 11 Field and Pool Alaska Oil & Gas Cons. Commission Anchorage KUPARUK RIVER 808' FNL, 653' FEL, Sec. 23, T12N, R8E, UM 5 Elevation in feet (indicate KB, DF, etc.) Rig RKB 41', Pad 53' 12 Date Spudded 23·Jul-96 17 Total Depth (MD+ TVD) 3725' MD & 3069' TVD 6 Lease Designation and Serial No. 13 Date T.D. Reached 24-Jul-96 18 Plug Back Depth (MD+ TVD) 56' MD & 56' TVD ADL 25547 ALK 2561 14 Date Compo , Susp. or Aband. 08-Aug-97 19 Directional Survey YES ~ NO D 115 Water Depth, if offshore 116 No. of Completions NA feet MSL 0 20 Depth where SSSV set 21 Thickness of permafrost NA feet MD 1650' APPROX 22 Type Electric or Other Logs Run GR/CCUCBT n~~, ~"NA~ . J .."\ .. , , 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD I CASING SIZE 16" 7.625" WT 62.5# 29.7# GRADE H-40 L-80 TOP SURF. SURF. BTM 121' 3715' HOLE SIZE CEMENT RECORD 24" 215 sx AS I 9.875" 770 sx AS III, 300 sx Class G Top job 40 sx AS III cement plug at 3040'-2940', bridge rlUg at 3040'; cement plug from 210' to 56', bridge plug at 210' TUBING RECORD 24 Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 25 SIZE N/A DEPTH SET (MD) PACKER SET (MD) 3065'-3067' MD 2588'-2589' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 3065'-3067' 260 sx AS III & 230 sx ASI Flow Tubing Press. Casing Pressure PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) N/A PRODUCTION FO OIL-BBL TEST PERIOI : CALCULATED OIL-BBL 24-HOUR RATE: GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 27 Date First Production Date of Test Hours Tested GAS-MCF WATER-BBL OIL GRAVITY-API (corr) 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A Form 1 0-407 Rev. 7-1-80 Submit in duplicate CONTINUED ON REVERSE SIDE ) " " ) 29. 30. GEOLOGIC MARKERS FORMATION TESTS MEAS DEPTH TRUE VERT. DEPTH Include interval tested. pressure data. all fluids recovered and gravity, GOR, and time of each phase. NAME N/A RECE\VED DEC - 2. 1997 . 'on . t, ka 0\\ & Gas Cons. comID\SS\ tvas Anchorage 31, LIST OF ATTACHMENTS Summary of Daily DrIlling Reports. Surveys 32, I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~~ ~ Title I)(¿L6.6.J6. DATE rz..f {/4.1- Prepared by Naij\e/Number ,- Sharon AUsup-Drake/263-46 1 2 INSTRUCTIONS Genera!: 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: It 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 ìnterval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method ot Operation: Flowing, Gas lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection. Gas Injection, Shut-ín, Other-explain. Item 28: If no cores taken, indicate "none". Form 1 0-407 , ARCa Alaska, Inc. ) Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 \ ~~ ~~ September 4, 1997 Mr. David J. Johnston Commissioner S tate of Alaska Alaska Oil & Oas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 30-25 (Permit No. 96-118/397-58) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the abandonment of KRU 30-25. If there are any questions, please call 263-4183. Sincerely, ~ D. K. Petrash Drilling Engineer Kuparuk Development DKP/skad "}r.. ;" '\ ' .~ ~\ \. ().\ .~, '-.. '\.~....) v' \~ '\ .~\ '\ .(1 \J S ("~~\\VJ <..\ 'V S 'V fV~~~' ~ fó'ð-f::J ~\~~ . ~~ fj. ~~~ ~fð.~ AR"CO\ Alaska, Inc. ) ) A KUPARUK RIVER UNIT WELL SERVICE REPORT JOB SCOPE JOB NUMBER RIG MISe SUPPORT 0808970011.1 DAILY WORK UNIT NUMBER P&A UNIT #3 OPERATIONCDMPLElli I SUCCESSFUL I KEYPERSON SUPERVISOR YES YES DS- WOLD ELLIS I Initial Tbg Press I Final Tbg Press I Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann o PSI 0 PSI 0 PSI 0 PSI 0 PSI 0 PSI DAILY SUMMARY PLUGGED THE 7-5/8" CASING FROM 3040' TO SURFACE: CEMENT PLUG 3040-2940',10 PPG MUD FROM 2940' TO 210', CIBP@ 210' & CEMENT PLUG TO SURFACE. Kl(3G-25(W4-6)) \VEL 30-25 DAlE 08/08/97 DAY TIME LOG ENTRY 08 :00 MIRU DOWELL cru #3. TGSM H2S MUS"æR AREA & JOB PLAN. 08 :30 MU 2.25" BALL DROP CEMENTING NOZZLE, STINGER & COIL CON~'EcrOR ON 1-3/4" COILED TUBING. 09 :00 PRESSURE TES1ED COIL & LUBRICATOR TO 5000 PSI. 09:30 RIHW/NOZZLEPUMPINGSW@2BPM. TAGGEDCR@3040'RKB. CIRCHOLECLEAN. ] ] :00 RU DOWELL CEMENTERS. CIRC & SPOTIED A 100' CEMENT PLUG FROM 3040' TO 2940' RKB WIl1-I 5 BBLS OF ARcnc SET I MIXED @ 15.8 PPG. 12: 15 CIRC HOLE VOLUME @ 2940' WITH 10 PPG MUD. 14:00 POHW/NOZZLE. ] 5 :00 MU 2.25" COIL CONNECTOR. PULL TES"æD TO 15,000#. MU 2.25" HYDRAULIC DISCONNECT. PRESSURE TES"æD TO 4000 PSI. MU BAKER MODEL J SETTING TOOL & 7-5/8" N-1 CIBP. ] 5 :30 RIH W/CIBP & SET@ 210' RKB. POH W/SE1TING TOOL. LD SE111NG TOOL. ] 6 :00 MU 2.25" BALL DROP CEMENTING NOZZLE. RII-I W/SAME & TAGGED CIBP@ 210' RKB. ] 6:30 CIRC & SPOTTED 175' CEMENT PLUG FROM 210' TO 35'RKB WIlli 8 BBLS OF ARCTIC SET I MIXED@ 15.8 PPG. WASHED CEMENT OUT OF WELLI-ffiAD TO 3' BELOW G,ROUND LEVEL. 01 :30 RD cru. Date: 8/12/97 ) ) ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 -------------------------------------------------------------------------------- -------------------------------------------------------------------------------- WELL:3G-25X RIG:PARKER 245 WELL ID: AK8589 TYPE: AFC:-AK8589 AFC EST/UL:$ 1175M/ 1410M STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:08/06/96 START COMP: FINAL: WI: 55% SECURITY: 0 API NUMBER: 50-103-20244-00 -------------------------------------------------------------------------------- -------------------------------------------------------------------------------- 07/19/96 (D1) TD: 121' ( 121) SUPV:DCL DAILY:$ 07/20/96 (D2) TD: 121' ( 0) SUPV:DCL DAILY:$ 07/21/96 (D3) TD: 121' ( 0 ) SUPV:DCL DAILY:$ 07/22/96 (D4) TD: 121' ( 0) SUPV:DCL DAILY:$ 07/23/96 (D5) TD: 1190' (1069) SUPV:GR DAILY:$ 07/24/96 (D6) TD: 3725' (2535) SUPV:GR DAILY:$ 07/25/96 (D7) TD: 3725' ( 0) SUPV:GR DAILY:$ 07/26/96 (D8) TD: 3725' ( 0) SUPV:GR/RLM DAILY:$ 07/27/96 (D9) TD: 3725' ( 0 ) SUPV:GR/RLM MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 MOVE RIG MATS Move drill and utility modules. 36,411 CUM:$ 36,411 ETD:$ 0 EFC:$ 1,211,411 MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 MOVE RIG Continue to move rig modules. 36,461 CUM:$ 72,872 ETD:$ o EFC:$ 1,247,872 MW: 0.0 VISC: 0 PV/YP: 0/0 APIWL: 0.0 PREP TO MOVE BALL MILL Move mats around drill module w/rollagons while moving ahead w/module. 36,411 CUM:$ 109,283 ETD:$ 0 EFC:$ 1,284,283 MW: 0.0 VISC: 0 PV/YP: 0/0 APIWL: 0.0 LOAD PIPE SHED Move CPM from 3F pad to 3G. Move drill module over hole. 36,311 CUM:$ 145,594 ETD:$ 0 EFC:$ 1,320,594 MW: 9.2 VISC: 58 PV/YP: 18/20 APIWL: 10.6 DRILLING 9-7/8" HOLE @ 2549' Nipple up diverter. Pre-tour safety meeting. Function test diverter and accumulator. Drill 9-7/8" hole w/MWD from 121' to 1190'. 89,780 CUM:$ 235,374 ETD:$ 0 EFC:$ 1,410,374 MW: 10.1 VISC: 52 PV/YP: 18/22 APIWL: 8.8 MONITOR FLOW Finished drilling surface hole. Trip out. Run casing. Lost circulation at 2500'. Run to bottom. Circ for cement job. 104,481 CUM:$ 339,855 ETD:$ 0 EFC:$ 1,514,855 MW: 10.0 VISC: 42 PV/YP: 8/15 APIWL: 12.4 RUN CBT Cement surface casing. Monitor annular flowback. Annular flow stopped. Ran cement bond log. 190,135 CUM:$ 529,990 ETD:$ 0 EFC:$ 1,704,990 MW: 10.0 VISC: 46 PV/YP: 8/17 APIWL: 8.8 CIRC THRU PERFS @ 3065' Monitor well. RIH w/bit and HWDP and drill pipe to 3495'. Circulate and change out water to mud. 99,277 CUM:$ 629,267 ETD:$ 0 EFC:$ 1,804,267 MW: 10.0 VISC: 43 PV/YP: 18/16 APIWL: 8.4 NIPPLE UP 13-5/8" BOPE Held safety meeting. Run in with drillable bridge plug and set at 3070'. Test 7-5/8" casing to 2000 psi for 10 bate: 8/12/97 DAILY:$ 07/28/96 (DI0) TD: 3725' ( 0) SUPV:GR/RLM DAILY:$ 07/29/96 (Dll) TD: 3725' ( 0 ) SUPV: DAILY:$ ) ) ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 minutes. No bleed off. RIB with perf gun. Shot 9 holes from 3067-3065'. Circulate through perfs. Bad 59 bbls heavily contaminated returns to surface. Monitor well. Returned all fluid loss. RIB with drillable cement retainer and set at 3008'. Cement casing and squeeze perfs. 80,824 CUM:$ 710,091 ETD:$ 0 EFC:$ 1,885,091 MW: 10.0 VISC: 42 PV/YP: 15/15 APIWL: 9.0 WAIT ON RETAINER Perform top job on 16" x 7-5/8" annulus. Test BOPE to 300/3000 psi. Drill out cement retainer at 3008'. Drill hard cement from 3008 to 3070'. 166,225 CUM:$ 876,316 ETD:$ 0 EFC:$ 2,051,316 MW: 10.0 VISC: 42 PV/YP: 15/15 APIWL: 9.0 RIG RELEASED Attempt to obtain test on squeeze perfs from 3065' to 3067'. RIB with cement retainer and set at 3040'. Pressure test casing and retainer to 2000 psi for 10 minutes. No bleed off. ND BOPE. Make up tubing head adaptor and master valve. Rig released at 1930 hrs. 7/29/96. 64,061 CUM:$ 940,377 ETD:$ 0 EFC:$ 2,115,377 ) \ 1& / f(Y: PAGE NO. *****************************~~*********************~**~**+ ********* ******~*~* XXXXXKXK* ANADRILL ~********* ********* SCHLU~BERGEF: *~*******~ ********* .****~*~*~ ***************************************************~*****~* AFE: AK 8589 . API: 50-103-20244-00 *********** SUF.1JEY PROGRAM 'fr'H·*~*H+* COMPANY ARCO ALASKA, INC. WELL HAI'IE 3G..25 LOCATION 1 KUF'A~'UI< LOCATION 2 ALASKA ~IC DECLINATION 27.69 GRID COi't'VERGENCE ANGLE 0.00 DATE: 29-JUL-96 IÆLL NtjI'lBé1\ 25 WELL HEAD LDCATIOH: LAT(N/-S) 0.00 DE~'(E/-:~; j.OC AZIMUTH FROM ROTARY TABLE TO TARGET IS 336.24 TIE IN POINT(TIP) I'IEASUF:ED DEPTH TRUE VERT DEF"I'H INCLINATION AZII'IUTH LATITUDE (N/-S) DEPARTUREŒ/-W) 121.00 . 121.00 0.00 0.00 0.00 0.00 ORIGINAL .... ".. ., '"'. ,. " '. ... ;.: ?AGE ¡~Ot ¿, " :Ï' _ ,~r ) \ .'.3) ********~**H ANADRILL H****HHHh SURVEY CALCULAiIG~¡S ************* C:~CULAR ARC METHCD******** :-r1EASURED :rnERVAL VERTICAL TARGET STATION <4ZIMUT)-ô ~ATIi:"::'E )EPAi::~l~RE :'~ r:;;PL,'~C'E~EHT ,~~: ŸZIMUi~1 ~\'I' f'\ :.il..j DEPTH DEPTH SECTION INCLN. N/-S Ej-w deg/ ft ft ft ft de<] cleq ft ft ft deq 100ft 121.00 0.0 121.00 0.00 0.00 0.00 0.00 O.C)V 0.00 0.00 0.00 283.93 M2.9 283.93 0.99 0.81 7.52 1 .co ~.lS . . I 7.52 'J.50 ...j,J J. . .1.':- 374./:.7 90.7 374.59 4.39 3.67 347.51 4.62 -0.39 4.64 355 . ¡ 4 3.22 4,S5 . 73 'il'.l 465.21 13.12 7.42 333.50 P ""1 - 3. IS5 ~3.24 344.01 4.:34 '-. I ... 555.99 '10.3 554.44 26.60 9.77 336.95 25 . OC -9.25 26.65 339.70 2.,~7 .S48.59 '1'2.6 645.44 43.67 11.61 345.02 41.23 -14.73 43.78 340.33 2.55 741.93 93.3 73·S .70 62.97 12.64 347-.58 60.27 -1~'.3b .:.3.31 342.20 1.24 ,~32.65 90.7 824.97 83.32 14.03 351.17 80.83 - '23.18 84 4 OS' 344. 0"0 :.ì9 925.76 93.1 914.83 107.07 16.32 347.33 lO4.ì5 -27.78 108.38 345.15 2.·SB 1017.02 '11.3 lOOl.6~ 134.86 19...70 345.12 :32. : ~ - '~;4 t ~:5 :3f...58 345.35 2.78 . 1:07.,,0 90.6 1085.65 168.33 24.04 341.84 164.45 -~4.23 170.2'1 :344.95 t,+9ì 11'7'9.31 '11.7 1168.57 207.37 26.53 3:39 '. 86 - 201. 44 -::.., ..,.. 2G"1t . 37 ~;4.1. i.7 2.87 -JI d',., 1293.22 93.9 1252.21 249.97 27 . 58 341.00 241.6'? - ì 1 . 4,:} 252~Ol 343.54 1.2.4 13B·~.lì n.9 1333.68 ,',4.55 29.94 340.76 283. 'ì4 -,Sb.05 2'1',S.6'1 343. 1 ~ '2.54 1475.78 89.6 1410.19 341.05 32.7i 33'7'.70 127 . 8C - 101 .2·4 343.2t. 342~74 ^ "'111I ,:. +" ~ lS~.9 .63 '13.8 1487.37 394.36 36.56 338 .03 :'377 . 5.~ <2LU 396.51 342.22 4.16 1658.06 88.4 1557.02 448.82 39.51 337.23 t.~i . 'i~ - ~.;~ .·~5 ~... '" c~ J 341 + 6.':. 3.39 .;,)V tI,;.q 1754.20 96.1 1629.49 511.96 42.63 337.97 48.~ 4 3~' -:65.91 513.85 341.16 '3.28 1844.2,~ 90.1 1,S94.90 573.80 44.22 339.33 543.':;'g - j, B,e, . ..~ 5ì5.ïC 340.81' 2.05 2121. 'i7 2ì7 . 7 1895.80 765.29 43.11 338.93 723+14 -256.74 ?bì.36 34\').45 O.4l 2396.83 274..9 2098.80 950 . 34 41.67 339.35 896.2,:· "''','-. -,'-, 952,62 340.20 0.53 -':"'Ll...l ~ 2673.46 27.S.6 2301.28 1138.62 44.22 338.1b 1071,91 .. :jl;: ~ . ~;.~. :141.02 329. 't6 ~ "'., V.7<' 294'7.33 275.9 2501.46 1328.37 42.73 336.81 1247.'2:- . ,'"' ..,,.., l330..67 339.(,1 0.64 ..~,,~, + ¡ ¡" :322.~, 4'1 277.2 2706.8'7' 1514.42 41.60 33" .3S' i418.;~'O -537.6: i516.4'; '339.24 0.42 3507.04 280.6 2912.24 1705.54 44.29 336.13 1592.S'~ - '7,14 .s.~ 1ì07 +3·, 338 . 90 0.96 3640.54 133.5 3008.27 1798.28 43.71 335.72 1677..,2 ,,6:';2.3'7' :8CO.OO 3~8.75 ·J.48 THE FINAL SUI\\lEY IS A PRû"TECTION TO TOTAL DEF'Th' '3725.00 84.5 3069.32 1856.64 43.71 335.72 1730.82 -¿,7h.3·! 1858.29 338.65 0.00 ************ **************** 1. Type of Request: 2. Name of Operator ) k. ') STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Rig RKB 411 Pad level 531 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3G-25 9. Permit number 96-118 10. API number 50-1 0 3 - 2 0 24 4 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 25381 FNL, 201 FWL, Sec. 24, T12N, R8E, UM At top of productive interval 13341 FSL, 16851 FEL, Sec. 14, T12N, R8E, UM (projected) At effective depth Abandon X Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension Stimulate Change approved program _ Pull tubing _ Variance Perforate Other 5. Type of Well: 6. Datum elevation (DF or KB) Development X Exploratory Stratigraphic Service At total depth 15501 FSL, 17801 FEL, Sec. 14, T12N, R8E, UM (projected) 12. Present well condition summary Total Depth: measured true vertical Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 37251 30691 measured 30401 feet true vertical 25691 feet Length Size 801 16" 36741 7-5/8" measu red 3067-30651 true vertical 2589-25881 Tubing (size, grade, and measured depth None Packers and SSSV (type and measured depth) None Description summary of proposal X 13. Attachments 14. Estimated date for commencing operation 4/1/97 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify t1t ~he. regoing is true and correct to the best Of. my ~nOWledge. Signed f ,.... ..~ Title Drill Site Dev. Supv. . " FOR COMMISSION USE ONLY Conditions of approval: No}ify ommission so representative may witness Plug integrity JL.' BOP Test _ Location clearance _ Mechanical InteJJrity Test _ Subsequent form require 10-_ t:ð"'P!J W"lifL (7~ charv~ Ungmal Signed By ,Approved by the order of the Commission David W. Johnston Form 10-403 Rev 06/15/88 feet Plugs Baker K-1 cmt retainer @ 30401 MD feet Baker N-1 bridge plug @ 30701 MD Float collar @ 3621' M D Junk None Cemented Measured depth True vertical depth 250 Sx AS I 1 2 11 770 sx AS III & 37 1 5 I 300 sx Class G Squeeze 260 sx AS III & 230 sx AS Top job 40 sx AS III 1211, 30621 t\C' . 'J ... l,c: H V t:O MA,R 2 0 199 " 7 "'¡U~~;ki:-7 n¡1 i~ .,.... ,....N ~ \'J1as C ;' >" .~~ r ",ons.. Gommi . OR;SINÂtfage SSwn Detailed operation program X BOP sketch 15. Status of well classification as: Oil --2L Gas Suspended _ Date ~'-(7~1 IApproval No. .0 I ~:¡ 71-5'0 Commissioner Date ~-c2:J-71 SUBMIT IN TRIPLICATE ( " ~ eò CO'P~ ~\PpI'O\1 d ~etUf~ ~ ) ) ~ ~ Kuparuk River Unit Well 3G-25 was drilled to the planned surface casing depth. The .....~ -..-lq) Ñ\'- hole packed off while running casing and no returns were seen during primary 1"'- \'~ cementing operations. In the course of subsequent operations, a bond log showed that ~ ~ C\. ~Q) the West Sak formation appeared to be inadequately isolated by cement. The casing ~ was perforated and squeezed in an attempt to perform remedial cementing operations. () ~ The squeeze perfs would not hold pressure after the squeeze. At this point the surface ~ 1 casing integrity was considered compromised in the event of well control problems, and 0 that further remedial attempts would not be economically justified based on the cost to ¿ '3 drill a new surface hole. The rig was moved off of the well. ~ L ~ ¡I~ ARCO Alaska, Inc. requests approval to plug and abandon the 3G-25 cased surface ~ "'- hole. The detailed procedure for plugging the well with a coiled tubing unit is attached. Lh Ii\ The procedures are designed to meet proposed regulations 20 AAC 25.105 and 25.120 b I requirements, with final operations delayed until abandonment of the active wells on the \..t." pad. ~ ~ ()~ In summary, a coiled tubing unit will place a 751 cement plug on top of the existing Baker ~~ K-1 cement retainer at 30401 (casing perforations are at 3065-30671 MD). A bridge plug :\J will then be set at 2101 MD and pressure tested to 2000 psi. A 1581 ArcticSet I cement J ~ J~ plug will be set from the retainer to 51 below the tundra level (TOC @ 521 MD). Kill ~ ¿ weight mud at 10.0 ppg will be left between the plugs. ~ ~ Currently proposed regulations require that the casing and wellhead equipment be cut --+.. ~ off 51 below tundra level during final well abandonment. AltOfn8.tiv~y, ARGO Alaska ~ i . t.oq,IJesto to Cllt off the VJ¿;IIhOfld and cä~lny ur I 3G-25 at th~ LJa~e uf th~ oolar (121 bolow ____ rd gr!l'dt.) as 11 tomporary ~t",f'. The final well abandonment ~e delayed unti~ other wells on DS 3G are abandoned at end of field life.þhere -are high cost and uperational impacts to grãV~1 and tunma removal in an effort to remove casing 51 below ~ tundra level. 3G-25 is located on an active drillsite and gravel will be maintained over the temporary abandonment, removing any concerns over exposed casing stubs. A $too~ plato,.will be weidÐ6 ever the cut casing with all required it,formatien bood-v\feldèd ) . ntc) it~ prior to backfilfing the cellar with gFavel and loveling the pad over the w~II site. ~ Requests to extend the temporary abandonment until final abandonment of DS 3G will be subm itted per the AOGCCls determ ination of proper frequency. __ __._~.-./ KRU 3G-25 P & A Cased Surface Hole As part of the abandonment operation, ARCO requests permission to haul any waste fluids (contaminated mud or diesel, cement rinse fluids, etc.) to the Parker 245 rig for disposal down a permitted annulus. The AOGCC field inspectors will be notified by the CTU Supervisors in advance of the abandonment operations so they can witness the cement plugs and pressure test of the cement retainer if desired, as well as the location clearance when all work is complete. If you have any questions or comments regarding the attached procedure, please contact Mike Zanghi at 263-6206 or the Drilling Engineer, Denise Petrash at 263-4183. r\CvC:J V cO MAR 2- 0 1997 OR\G\N~l Alaska Oi~ & Gas Cons, Commission ,?\l1chO\~age ) ) KUPARUK RIVER UNIT WELL 3G-25 Current Status Illii ~ illlili :¡;:::::¡;:::~ diesel to 2200' Baker K-1 cement retainer @ 3040' (on drillpipe) Tested to 20Klbs & 2000 psi 7/29/96 10.0 ppg mud ~it. 10.0 ppg mud :::.::::.: ~i~:t.~ ,;;:::::;;::::~ ~¡~:::~}::: Baker N-1 drillable bridge plug @ 3070' (on Eline) Tested to 2000 psi 7/27/96 ~ I J ~.; ,- ;~ - r 10.0 ppg mud TD @ 37251 16" Conductor to 121' Cemented to Surface Top job w/12 bbl ASIII 10.0 ppg mud and water spacer Top of ASIII from squeeze calculated @ 845' w/guage hole Perfs from 3067-3065', 9 holes Squeezed w/90.7 bbl ASIII & 42.1 bbl ASI Top of Class G estimated @ 3230' based on CBT log 7-5/8",29.7#, L80 Shoe @ 3715' Cemented with 770 sx AS III and 300 sx Class G in primary job ALL DEPTHS ARE MEASURED DEPTHS PARKER 245 RKB = 41.5'. DKP 8/96 ) ) KUPARUK RIVER UNIT WELL 3G-25 P&A Plan casin(:2?~e::a::d o~~:~:~ ~:~~:~;:!~~pY:~'~~~~;~~S::'~~N:~!~:!~~;~¡~j .:....:.....".::...:.,.: ±158 of ASI ".::...::....:...::.... and dry hole marker put on :~:J{:}:{::~:~ to 51 below :¡~:::{:::~:::{::::f 16" Conductor to 121' ~::::::._:: ground level "':::~::~ Cemented to Suñace .:.... . :::'..:.,': (TOp @ 521 MD) "::.....::.. ...... . ".:: :;.::.:;.....;.:..................... .,,:;.::.:;.:~...... '. .'. .'. ...... ..... .'. ...... ......... .... ~ bridge plug @ 2101 MD ...........:...:...:...:...:...:...:........ Top job w/12 bbl ASIII 10.0 ppg mud and water spacer Original ground level = 47.31 above MSL Pad level = 52.61 above MSL Parker 245 rig RKB = 41.5' 10.0 ppg mud Baker K-1 cement retainer @ 30401 (on drillpipe) Tested to 20Klbs & 2000 psi 7/29/96 .:;:.:..:;:.:. 10.0 ppg I ,~;;:::~~:::~ '~''':::~ :H::t::: mud Baker N-1 drillable bridge plug @ 30701 (on Eline) Tested to 2000 psi 7/27/96 TD @ 3725' Top of ASIII from squeeze calculated @ 8451 w/guage hole Perfs from 3067-30651, 9 holes Squeezed w/90.7 bbl ASIII & 42.1 bblASI Top of Class G estimated @ 32301 based on CBT log 7-5/811,29.7#, L80 Shoe @ 3715' Cemented with 770 sx AS III and 300 sx Class G in primary job ALL DEPTHS ARE MEASURED DEPTHS - PARKER 245 RKB = 41.51. DKP 3/97 ) ,) Procedure for CTU P& A (Temporary) KR U 3G-25 AFC# AK8589 ARca Alaska, Inc. DRAFT Prepared By: ----------------------------- Drilling Engineer Date Approved By: ----------- ------------- Drill Site Dev. Supervisor Date Distribution: KRU Well File (3G-25) W2 M. Zanghi ATO-1276 J. B. Kewin NSK 69 Bradley/Ellis NSK 69 Parker 245 NSK 12 Please see attached schematics for the current status of 3G-25. Important points for the CTU P & A: · Casing is 7-5/811 29.7# L-80 BTC Mod. · No perfs are open. · There should be no pressure on the well. · The well was left with the master valve topmost, no tree (3-1/811 5000 psi flange). · Diesel was circulated into the well at 22001 MD. 10.0 ppg mud is below that. · A Baker K-1 cement retainer is set at 3040' MD and was weight tested to 20 Klbs and 2000 psi on 7/29/96 prior to the rig leaving the well. · The AOGCC field inspectors should be notified 24 hrs prior to commencing the P&A in case they wish to witness the abandonment operations. Summary of CTU Work: 1. Circulate out diesel at 22001. Save for use later for freeze protection. 2. Circulate 10.0 ppg mud and balance wellbore fluid. Mud can be sent to Parker 245 for disposal if the rig is pumping down an annulus, or to a dedicated disposal well if not (with appropriate paperwork). 3. Lay minimum 751 Arctic Set I cement plug on top of Baker cement retainer at 30401 MD. 4. Leave 10.0 ppg mud on top of the cement. . We do not need to tag the plug as the retainer has been tagged and pressure tested previously. 5. Set a mechanical bridge plug at 2101 MD to 'provide support for the surface cement plug. Lay ±150' of Arctic Set I from the BP to at least 52' MD. With Parker RKB of 41.51 this will bring the cement top to within 51 of below original ground level as required by proposed regulation. 6. Wash .the top of the plug at 521 MD with water to be sure that there is no cement or diesel in the wellhead, tubing spool, or adapter. The wellhead will be cut off and the equipment recovered for future use once the cementing work is completed. 7. Please notify the Parker 245 Rig Supervisor just prior to beginning work and once the work is completed, so that welders can be brought over as soon as the CTU is off the well. 8. Record the bridge plug depth, pressure test results, cement plug volumes and blends, and any other pertinent information. Send to Denise Petrash so the final paperwork can be filed with the AOGCC. ) ., pttt'i po¡-~t- Summary of Drilling Work: . ~. . 1. Once notified of the completed cemen P & A work, have welders cut the 1611 conductor and '7-5/811 casing at the~ .. of the cellar. Note that a top job was done on this well so cement will have to be removed from the annulus. Begin the cutting operations as soon as possible as the very top of the well will not be freeze- protected in anticipation of the welding .occurring. Return all recovered equipment back·to FMC for cleanup and reuse. r-2. Weld Ci ~teel platê over the l;Cislng StubS: 1/411 thicK and rlli'1ilYIUlll uf 1 S" square 0,"\ in diameter. On the plate ~urface bead-weld the following information: ARCO Alaska, Inc. KRU Well 3G-25 fJof- .ÚVlht .ç;n~( aÞ~~ep\.£ Permit #96-118 API #50-103-20244 3. Backfill the cellar with gravel and level the pad oveJ the well site. 4. Notify the AOGCC field inspectors when work is completed so that a final site inspection can be done. ) -----.J A request to extend the temporary abandonment will have to be submitted yearly to the AOGCC. If there are any questions about this procedure please call me at x4183. D. K Petrash Drilling Engineer ) ) " 1?1D" MEMORANDUM State of Alaska ¡ Oil AND GAS CONSERVATION COMMISSION o a.. rJ\d Pðfe f(v:~.. a.+toA..d. 1'7 '1 fo ôo-r #(CG Nt .Q^-h~ ~~ r Cø-Ir;. "'"¡ "C. ,.e!rQ r Q. -v:;...a ~.~ -rlv..., ad..«, 'fo c:J u-r d o..+ø... 'S' CÅf,' p'''rh ':J cO I"k.,Q ~ +r~ ~rc.. ~q, "Q/H'ld-fl"':t-:t+_ ... tß~ ,2,( {ó Sbj: Surface casing cementing results since the 7/31/91 directive (file: c:\aogccgen\dirsumry.doc) q (¡¿ -- / I Z 1. KRU 3G-25 - - Chronological Summary - after July 25, 1996 sfc CSQ cmtQ * Unable to circulate below 2500' while running 7 &5/8" casing to bottom at 3677'. * Pumped 266 bbls AS III lead and 63 bbls tail - no returns. * About 1 hr after bumping plugs, annulus started flowing clabbered cement and mud. * Had lost -1100 bbls mud and cement; annulus flowed -460 bbbls before nearly dead. * ARCO wanted to do a top job, drill out, leak-off test, and proceed accordingly. * Cement bond log showed top of cement at 3260-40'; top of W Sak at - 2900'. * Well was cemented 3677 to 3250 = 427'; uncemented from 3250' to the surface. * Shot holes at 3067-65' & was able to circulate; recemented - lost return~ on Jead slurry. * PIT csg above retainer to 2000 psi; PIT squeeze holes to 250 psi, bled to 95 psi in 2 hrs. December 16, 1996 / To: Commissio~ ~ Frm: Blair Wondzell I aU6 2. Commissioners issued directive effective July 31, 1 996 to fully cement surface casing. 3. Well KRU 3G-25X did not get cement to surface of August 8 so they left well suspended. 4. Well MPU F-21 did not get cement to surface on August 13; ran SBL which show good cement to -- 3140' and scattered cement to -- 2450' . BPX left well suspended. 5. Summary: A. Since KRU 3G-25 thru 11/17/96, ARC a has drilled 11 KRU wells - all have obtained cement-to-surface or were remediated. B. Since MPU F-21 thru 12/8/96, SSD has drilled 23 North Slope wells - aU have obtained cement-to-surface or were remediated. C. The last 34 North Slope wells have either circulated cement to surface or have been remediated. 6. Comment: The record of successful surface casing cementing that has occurred since August 13, 1996 shows what is possible when industry tries. Cementing Permafr, ) Casing (References) Page 7 . Added after the November 20 , 1 996 Public Hearinq ) ARCO Alaska Inc., Standard Alaska Productions CO., and Exxon Co., USA SURFACE CASING REQUIREMENTS FOR PRUDHOE SAY WELLStI Report Prepared for STATE OF ALASKA, OIL AND GAS CONSERVATION COMMISSION, April 1987, Sbj: casing design requirements for strains within the permafrost. From the INTRODUCTION, these statements The functions of the surface casing during production are: (1) to help support the wellhead, (2) to isolate the production casing from permafrost loads, and (3)'to provide back-up pressure containment. From CASING FAILURE MODES, these statements Two failure modes are considered for loss of pressure integrity due to compressive casing strain. They are thread jump and a crack in a large circumferential bulge, or buckle. Buckling results in failure when the circumferential bulge grows large enough to bend over and contact the edge of the coupling, resulting in a through-wall crack. The casing failure mode can be determined by physical testing or by detailed simulation of the thread connection. It is assumed that using shouldered connectors would prevent a thread jump failure, establishing bulge formation as the failure mode. From ALLOWABLE CASING STRAINS, this statement A Bulge large enough to cause a crack can only form where the casing slips relative to the soil. Because the strain capacity of the casing is lowest for long slip lengths, ......... APPENDIX 0, PROCEDURE TO CALCULATE CASING STRAIN CAPACITY, these statements: The following assumptions simplify the casing-soil interaction model: A buckle large enough to cause a crack can only form where the casing slips relative to the soil. The shear stress applied to the outer diameter of the casing over the slip length is equal to the failure shear stress of the soil. -The presence of the cement around the outside of the casing was not considered in the model. This omission only adds further to the conservatism of the modeling. Step": (1) axial compressive strain versus casing length, shown in Figure 0- 1, . .. From Figure D-1 IIOVERALL AXIAL COMPRESSIVE STRAIN AT FAILURE-IN/IN" versus IICASING LENGTH-FTtI: at 2 ft strain is 0.115; at 10 ft is 0.04; and at 60 ft is 0.022 - this is a decrease in strain capacity of 810/0 7 Well KRU 3G-25 Kic July 25, 1996 Page 3 } :) 1 :45 pm - Fred Johnson called and proposed perforating at 2900', top of W Sak, circulate if possible otherwise squeeze perfs. Cement lead if circulate AS III, followed By AS I tail ( has better compressive strength than AS III and in cool conditions, better than "G" in the short term); if squeeze would use AS I. 2:00 pm - Discussed with Bob Crandall, W Sak would be protected with cement squeezed above it. 2: 10 pm - called Bobby, we propose shoot at 2900'. Circulate if possible with AS III, then AS I followed by 10 bbls of G leaving 5 in and 5 out. If squeeze, do hesitation squeeze with AS I followed by 10 bbls of G, 5 in and 5 out. If well - annulus is dead dead, can do top job and then drill out for LOT. 2:40 pm - Fred Johnson returned my call, I related our modified proposal; he presented information that AS I sets up to 500 psi in 2 hrs at those temps versus only 50 psi for class G. We agreed to go only with AS III and AS I if we circulate, & AS I for squeeze. PIT pressure will depend on final squeeze pressure. 7/27/96 9:30 am - Bobby called and said they had shot the holes at 3067-65' and were now circulating to clean up the annulus. They will cement later to day (7/27). 7/28/96 9:00 am - Bobby called and reported that they had cemented the well with _ bbls AS III and 41 bbl AS I. They lost returns while pumping the lead slurry and ended up doing a hesitation squeeze with the end of the tail slurry; the last stage was at 0.2 bbl per minute. The final squeeze pressure was about 800 psi. Will test the casing to 1000 psi. Well is dead. 4:00 pm - Fred Johnson called and briefed me on the progress and said they were trying to salvage the well. He said they had a final squeeze pressure of about 800 psi which bled down to about 625 psi. Their concern was for casing integrity; therefore they wanted to test the casing before drilling the retainer to 2000 psi, drill out and run a PIT to 11.5 ppg EMW. At the top of the Kuparuk where they needed to make a decision to "top set" or drill the Kuparuk, they would do another PIT to 12.5 ppg EMW. Anticipated mud weight to top of Kuparuk is 9.6 ppg, current mud in the hole was 10 ppg. 4: 15pm - Bobby called to discuss the program Fred and I had talked about. We agreed the 11.5 ppg EMW was on the low side for the Kuparuk, but provided approx. 2 ppg margin for drilling above the Kuparuk. Bobby and I believe that the squeeze job is probably better than they think it is and we will be happy to see the 12.5 ppg PIT at the top of the Kuparuk. We also agreed that we wanted them to complete this well - not good if a well in which we participated in active decisions could not be completed. 7/29/96 9: 15 am - Fred Johnson returned my call, he reported they tested above the retainer to 2000 psi, drilled out the retainer and tested to 250 psi which bled down to 65 psi in 30 minutes - second test, pressured to 250 psi bled down to 95 psi in 2 hrs, still dropping about 4 psi in 5 minutes. Now plan to set a retainer above the perfs, pressure test and then do an operation shut down. May move in a cheaper rig (coil tubing) to do another squeeze). 3 ) ,0--',. ,,,,.'~ ir- B ',g b ·W'';) r{ t: t..: t:. ~ "~.g Ln: ARCO Alaska, Inc. '" --- 2 .', ~\(}9h ~c.t.J _ J... rd' ."""'" '.'.,'~r~;';'~.'.' {~(~~.",.~:~;:~~ ~;0fn(n~~ì$!O~1 j~'~.j <~ ~i ;~~., ~~: ? "- -.v 'Y .,. \nç¡"!(::~&~;e ) ~-... ~~ Date: September 11, 1996 Transmittal #: 9735 RETURN TO: ARCO Alaska, Inc. Attn. : Bethany Lilly 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. q~'/I'8 3G-25 g{g~ fO~ 3F-19 q(g' /12- 3F-18 q~~H~ 3F-17 C{(q. ö~o 2M-35 q ~. 01<12M-34 Cement Bond Log Cement Bond Log Cement Bond Log Cement Bond Log Cement Bond Log Cement Bond Log 07 -25-96 07 -27 -96 07 -26-96 07 -27 -96 07 -28-96 07-31-96 Receipt O~ . C h-1 AcknowledgeO /~ I Date: DISTRIBUTION: Sharon Allsup-Drake OS Development ATO-1205 Larry Grant (+sepia) AOGCC 3001 Porcupine Drive Anchorage, AK 99501 2700-3520 7460-7876 6000-6770 6460-7045 14000-14775 1 6240-16560 Chapman/Zuspan NSK Wells Group NSK69 ) MEMORANDUM ) State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johns / Chairman-~ . DATE: July 25, 1996 THRU: Blair WondzellT ekf('16 P. I. Supervisor JÐ C Bobby FOS~ Petroleum Inspector FILE NO: YCXIGYDO.OOC FROM: SUBJECT: Surface Cement Job ARCO - KRU - 3G-25 PTO #'96.:.0118 Kuparuk River Field Thursdav. Julv 25.1996: I traveled this date to ARCO's KRU well 3G-25 to find out what time the rig would be ready to test their BOPEs. When I arrived at the rig I was informed by Granville RizksT Parker Drilling SuperintendentT who was also filling as ARCO drilling foreman, that the well was flowing. The events that led Up to this are as follows - The crew had run the 7.625" casing to approximately 1700'(40 jts.) where they stopped and broke circulation. Between 60 and 70 joints in they lost returns as they was running in the hole. They lost approximately 79 bbls. of mud while trying to break circulation. The crew then ran the casing on to bottom with no returns. They then pumped 444 bbls. of 10.2 Ib/ga!. while reciprocating the pipe which was free and lost all 444 bbls. of mud. They then pumped 266 bbls. of lead cement (12.1Ib/ga!.)T 65 bbls of tail slurry (15.8 Ib/ga!.) and displaced with 163 bbls of 10.2 Ib/gal of mud at which point they bumped the plug - with no returns except a small trickle on the upstroke while reciprocating the casing. Granville told me that he went to camp at about 5:00AM to call the drilling engineer to inform the engineer what went on during the job and to find out what to do next. He said the driller called him at approximately 5: 15 AM and informed him that the well was flowing. From that time until I arrived on location at 8:00 AM the well had flowed 436 bbls. and from 8:00 AM until 9:00 AM the well flowed another 10 bbls.. At approximately 8: 00 AMT Bobby MorrisonT ARCO drilling foremanT arrived from another rig. He and I spoke with Mike WinfreeT acting ARCO drilling manager, and it was decided to let the well flow and see if it would stop and to get Schlumberger get rigged up and run in the hole with a perforating gun in case they had to pump heavy mud in to kill the well. No hole was to be shot until it was necessary due to increased flow. I agreed with this plan and departed the location for another job. I checked by phone with Granville at 2:45 PM and he said the well had almost quit flowing and they were still watching it. I went to the rig at 5:30 PM and observed the flow line and there was a small trickle of mud coming out. · . ) ) At this time I ask Granville what they planned to do next. He said they were going to run a bond log to find the top of the cement. I told him to call me before they got through logging so I could see what the results of the log were and I departed the location. FRIDAY, JULY 26. 1996: I arrived at the location at 7:00 AM and Granville informed me that the E-line unit had finally got the cement bond log run and we looked at the log. I decidèd that the top of the cement was at 3160' but since I am not that familiar with logs I went to the logging unit and spoke with Dave Lucas, Logging Engineer, and Amy Smith, Station Manager, and found that they agreed with me as to the TOC. Amy and Dave both said above this point they saw no cement. I returned to the rig camp and met with Granville about the options. I told him that decision was up to ARCO but the only one I could see was to perforate the casing above the TOC and try to break circulation and pump slurry. My supervisor, Blair Wondzell, paged me and I returned his call. He said that he had been contacted by ARCa in Anchorage concerning moving the rig off the weiland waiting until a tater date to run a bond log to see where the TOC ( Permafrost) was. I told Blair that the answer was no because the well had flowed a small amount after setting for 10+ hours with nó flow. Blair agreed with me and said he would talk with ARCO and contact me later. At 1 :50 PM Blair called and informed me that ARCO would perforate the casing at 3,000' and try to cement squeeze the formation at this point. I disagreed with Blair about trying to squeeze but we decided jf they could circulate we would re-cement the upper porition of the hole. SATURDAY, JULY 27, 1996: I was contacted by Bobby Morrison this morning informing he had a game plan. I went to the rig and a cement retainer had been set at 3070' and the casing had been perforated from 3067 to 3065'. Another retainer was run on the DP and set at 3008'. The cement job began by pumping 20 bbls of fresh water down the drill pipe at a rate of 2 bblslmin., a rate that was never exceeded during the entire job, followed by 84 bbls. of 12 ppg Arctic Set III and at this point circulation was lost. Another 6+ bbls of slurry was pumped for a total of 90+ bbls. A 41 bbl. slurry of Arctic Set I was then pumped and the last 18 bbls were" hesitated squéezed" into the formation at a rate of .2 to .5 bbls/min. at 0 pressure to a final pump pressure of 850 psig. When the pump was shut down the pressure fell to 625 psig and held for approximately 2 minutes. The stinger was pulled out of the retainer and the DP was circulated. The cement was in place at 10:07 PM. The annulus volume of the hole from the bottom perforation to the surface was 33.3 bbls if the hole was in gauge and with the amount of fluid pumped would put the CTC at 845' . Since the holes usually wash out Bobby Morrison and I estimated the TOC to be between 1,000' and 1400'. This does not meet the AOGCC regulations but since I felt that the West Sak sand and the Ugnu formation was covered and ARCO had made a very good effort on remedial work, Blair and I agreed to accept it and approved the setting of a top job. ') q G -I(~ Memo: ARCO: Well KRU 3G-25 Kick: 25July96 To: David Johnston Tuckerman Babcock Jack Hartz Bob Crandall 25July96 last rev 8/14/96 Fm: Blair Wondzell c:\aogccgen\kru3g-25. kic) Chronological Summary * Unable to circulate below 2500' while running 7 &5/8" casing to bottom at 3677'. * Pumped 266 bbls AS III lead and 63 bbls tail - no returns. * About 1 hr after bumping plugs, annulus started flowing clabbered cement and mud. * Had lost -1100 bbls mud and cement; annulus flowed -460 bbbls before nearly dead. * ARCO wanted to do a top job, drill out, leak-off test, and proceed accordingly. * Cement bond log showed top of cement at 3260-40'; top of W Sak at 29_'. * Well was cemented 3677 to 3250 = 427'; uncemented from 3250' to the surface. * Shot holes at 3067-65' & was able to circulate; recemented - lost returns on lead slurry. * PIT csg above retainer to 2000 psi; PIT squeeze holes to 250 psi, bled to 95 psi in 2 hrs. Observations * Should make short trip when pulling out to run casing; this was not done on 3G-25. * They were unable to circulate at 2500' while running csg; they continued to bottom and pumped 444 bbls of 10.2 ppg mud with no returns. They knew that they could not circulate cement to surface when they started pumping cement. They should have pulled the casing out of the hole when they first found that they could not circulate. Chronology of Events 7/25/96; about 10 am Bobby Foster called and reported that on KRU well 3G-25 they had planned to set 7&5/8 sfc casing at 3677', below the Ugnu and the West Sak sands. After drilling the 9&5/8" hole they started running casing. At 1700' they were able to circulate; as they went in the hole, mud would not circulate, but they continued to bottom after running 86 jts. of pipe. On bottom they pumped 444 bbls of 10.2 ppg mud with no returns except a trickle on the up-stroke while reciprocating. They then pumped 266 bbls of permafrost cement @ 12.1 ppg followed by 63 bbls of 15.8 ppg tail cement "'G" and displaced with 163 bbls of 10.2 ppg mud, all with no returns. They did not do a "top job", the well started to flow. By 8 am this morning, the well had flowed about 436 bbls of 8.8 to 9.9 ppg fluid, between 8 and 9 am this morning the well flowed an additional 10 bbls of 9.3 ppg. One chloride measurement was 24,000 ppm - I don't have data on any other measurements. (I told Bobby we would want to see a valid lot on this well). About 10:30 am Denise Petrash, ARCa engineer assigned to Parker Rig 245 called and reported that methane had gone from 0 to 20% to 8% currently. their geologist thought that it was gas hydrate gas. The fluid was clabbered cement/mud; since the sands behind pipe were fresh, the chloride content of the flowing fluid was thought to be from the permafrost cement, Arctic Set III, which had a chloride content of 60,00 ppm. They are now preparing for all situations. They had a Schlumberger truck heading for location to Well KRU 3G-25 Kic' ) July 25, 1996 Page 2 \. l shoot circulating holes in the casing (hopefully, after locating the top of cement). Denise said they would keep me informed as to their plans. 3:30 pm: Denise called and reported flow was down to 1.5 to 2 bph, chlorides 10,000 ppm, mw 9.6 ppg, & no gas. Think they lost about 1100 bbls total, probably to the Ugnu formation, and got about 460 bbls back. (Q. formation packed off during cementing, but why did the pack-off dissipate?). Based on the delta psi increase, they think they got tail cement around the corner (plug bumped correctly) and they have tail cement above the shoe. ARCQ's plan is to do a top job, drill out, do a leak off test, and proceed accordingly. I asked about plans to shot and squeeze or circulate - she said they did not want to jeopardize the integrity of the well. She also said the Ugnu was wet at this location. I told her to hold up, don't do a top job and we would get back to her shortly - she asked how long, I said about 20 minutes. She said OK. Jack, Bob, and I huddled, David joined us a few minutes later. Bob agreed that the Ugnu was wet at that location but believed the West Sat was potentially productive. We considered the various options, including ARCQ's: 1. Top job, drill out, lOT. 2. locate top of cement, shoot squeeze, drill out, lOT, top job. 3. CQl, if not above W Sak, shoot & squeeze, top job, drill out & lOT. 4. Drill out, lOT, shoot & squeeze, top job. After some discussion, we decided to call Denise and relate the following requirements: 1. W. Sak is probably productive at that location. 2. We have no assurance that the W. Sak is covered. 3. Do some program to provide that assurance. 4. Do not do a top job until approved by the Commission. I called Denise & related the above, she said ok. I gave her my home phone. 8: 15 pm - Bobby called and said Schlumberger was preparing to run a cement bond log. I updated Bobby as to our meeting and instructions to Denise. He said he would keep track of the operation. 7/26/96 10 am - Fred Johnson, ARCO called, CBl top of cement at 3200', top of W Sak at 29_'. lost 1100 bbls, annulus started flowing about 1 hr after bumping plug. When running in with casing no circulation below 2500'. Says W Sak is not productive at this location (good logs on 3G-11). Does not want to shoot and circulate/squeeze. Says it will jeopardize well integrity. Said annulus is now dead; asked about moving off - what would be necessary. 10:30 am - talked to Bobby, TOC 3240-3260, tagged cement at 3520 103' above float collar. Still trickling from annulus on about 30 minute cycles. Does not want the rig to move off. Does not want the well abandoned unless the W Sak sands are covered. 10:40 am - Talked to Bob Crandall about the West Sak being wet. He checked logs on 3G-11 and W Sak 25548-11 and said it has good saturation; he called and talked to Fred Johnson. 11 :00 am - I called Fred Johnson and told him that whether they completed the well of abandoned it, they needed to shoot and circulate/squeeze the W Sak and above. I suggested shooting at the top of cement as shown on the CBl and circulating or hesitation squeezing - if squeezed, come up to where they were able to circulate when running the casing, shoot and circulate cmt. 2 ) ) SUMMARY: I witnessed the remedial cementing work done on ARCQ's KRU well 3G..25 surface casing after the rig did not receive cement back to surface on the initial job. MONDAV. JUL V 29.1996: I notified this date by Bobby Morrison that the perfs in the casing would not hold the pressure test and they would set a retainer and move the rig to another well. Attachments: Cement Bond Log of well 3G..25 /0 ~:~;:::; 1"7\ c¡;: r.=J ( ;', L.. l' i ,I;, \, 1 1 ''<'\ i ¡ / d \1¡ ? ;-"':: !! /1""" \ ,I 1 '; \~.I" I:,:' :1 ,...., '....-" ........, ..~ \_:.~ ~~ ¡,I,~F¡,~\ r? rp n' ,/~-\ 0:=ù 1l/7 j}\\' 1111' ',) /¡\\ I 1/11\ ~ ! "it 1\\ ,I : I .j, ¡ I LJ .., ì ~ ! Ll ~} 'L.; ¡.Jï¿ L.b LrlJ @ U ~ U\J ) TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE -ANCHORAGE, AU\SKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 10, 1996 M. Zanghi, Drill Site Develop. Supv. ARCa Alaska, mc. P a Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 3G-25 ARCa Alaska, Inc. Pennit No: 96-118 Sur. Loc. 2538 'FNL, 20"FWL, Sec. 24, T12N, R8E, UM Btmhole Loc. 1550'FSL, 1780'FEL, Sec. 14, T12N, R8E, UM Dear Mr. Zanghi: Enclosed is the approved application for pennit to drill the above referenced well. The pennit to drill does not exempt you from obtaining additional pennits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Approval for annular injection is contingent on the operator's submittal of an Application for Sundry Approvals (10-403) with pertinent facts and evaluation of surface hole conditions, casing placement, cementing, and any diagnostic logs that were run. The documentation submitted should include a CQL or a valid LOT to assure the Commission that an adequate seal has been attained and that the well has been cased and cemented according to regulation. 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. _~~·.i2~~elY' --~,. C ........'; - \ \ '. . '-. ..., .....-...,;7. -' David W. Johnston, Ch 'rman ~- BY ORDER OF THE- dlflEnclosures cc: Department of Fish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. . . \ .:"... " -'. .. .. ~ .. " . . '<. ) STATEOF~ ) ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 Redrill 0 1 b Type of Well Exploratory 0 Deepen 0 20. Attachments Filing fee X Property plat 0 BOP Sketch X Drilling fluid program X Time vs depth plot 0 Refraction analysis 0 21.~. ce~¡fy that the fOreg. oing is true and correct to the best of my knowledge Signed .. }~Þ--' ~ ^^'~ b..L-""\k: Title Drill Site Develop. Supv. .....J Commission Use Only pe~~~be# 8 I ~~~ /~3 - 2.. 0 2 ~ 7' I Approval date 7 J I ðJ 9 ~ Conditions of approval Samples required 0 Yes œ No Mud log riqu¡rk 0 Hydrogen suUide measures Jm Yes 0 No Directional survey required S Yes Required working pressure for BOPE 0 2M 181 3M 0 5M 0 10M 0 15 M 1a. Type of Work Drill X Re-Entry 0 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 25381 FNL, 201 FWL, Sec. 24, T12N, R8E, UM At top of productive interval ( 41 TARGET) 13341 FSL, 16851 FEL, Sec. 14, T12N, R8E, UM At total depth 15501 FSL, 17801 FEL. Sec. 14, T12N, R8E, UM 12. Distance to nearest 13. Distance to nearest well property Ji.!:: -: . 3 G -1 3 3500 @ .W{·· feet 11.81 @ 4751 .'" ~ ,... . -.... 16. ·;t9diJi! oompl~(a;t (or deviated wells Kickó1f"ëtepth· '. 3001 feet Maximum hole angle 18. Casing program size Hole Casing Weight 24' 16' 62.5# 9.8751 7.625' 29.7# 6.751 Specifications Grade Coupling Length H-40 Weld 801 L-80 LTC 36361 HF-ERW 15.5# L-80 LTCM0c- 72101 HF-ERW 12.8# L-80 EUE8rdM 4251 5.5' 6.751 4.5' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet true vertical feet Effective depth: measured true vertical Casing Length Size Structural Conductor Surface Intermediate Production liner Perforation depth: measured true vertical Other: Uriginal ~¡º.. ~~ David W. Johnstoì Approved by Form 10-401 Rev. 7-24-89 Stratigraphic Test 0 Development Oil X o Service 0 Development Gas 0 5. Datum Elevation (DF or KB) Rig RKB 411, Pad 531 6. Property Designation feet Single Zone X Multiple Zone 1 O. Field and Pool Kuparuk River Field Kuparuk River Oil Pool ADL 25547, ALK 2561 7. Unit or property Name 11. Type Bond (see 20 MC 25.025) Kuparuk River Unit 8. Well number Statewide Number 3G-25 9. Approximate spud date ~/15/96 14. Number of acres in property #U-630610 Amount feet $200,000 15. Proposed depth (MO and NO) 76761 MD 2650 60391 TVD 17. Anticipated pressure (see 20 AAC 25.035(e)(2» Maximum surface 1 8 0 8 pslg At total depth (TVO) 3200 Seni~ Depth feet 41.7° pslg Top Bottom Quantity of cement tv£) TVD tv£) TVD (include stage data) 411 411 1211 1211 ±200 CF 411 411 3677' 30541 1000 Sx Arcticset III & 300 Sx Class G 411 411 72511 57211 130 Sx Class G 72511 57211 76761 60391 Top 5001 above Kuparuk Plugs (measured) feet feet Junk (measured) Cemented Measured depth True Vertical depth RECEIVED JUN 2 5 1996 Alaska 011 & Gas Cons. Commission Anchorage Diverter Sketch X Drilling program X Seabed report 0 20 AAC 25.050 requirements X Date b ' E.b {crb I See cover lener for other requirements Yes ~ No o No Commissioner by order of the commission Dal. f /iii?7nDI~t. ) ') GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD KRU 3G-25 1 . Move in and rig up Parker #245. 2. Install diverter system. 3. Drill 9-7/8" hole to 7-5/8" surface casing point (3,677') according to directional plan. 4. Run and cement 7-5/8" casing. 5. Install and test BOPE to 3000 psi. Test casing to 2000 psi. t~a.~ ð~ DP fD C3w 1(1(<¡f. ~:~,,:~:~i(brill out cement and 10' of new hole. Perform leak off test to 12.C ppg EMW. ~,~:; ~·:~f"~ .r." ~{:..~ ,';:':~~1-..' ·-:..~·t>rill 6-3/4" hole to total depth (7,676') according to directional plan. 8. Run open hole evaluation logs or LWD tools as needed. 9. Run and cement 5-1/2" x 4-1/2" tapered casing string with polished seal bore as part of XO. (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.) 1 O. Pressure test 5-1/2" x 4-1/2" casing to 3500 psi. 1 1 . Run completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus. 12. ND BOPE. NU tubinghead & master valve and upper tree assembly. Note: As a dedicated producer, no cased hole cement bond logs will be run unless there are problems with the cement job. 1 3. Shut in and secure well. 1 4. Clean location and release rig in preparation for perforating. RECE1VED JUN 2 5 1996 Alaska 011 & Gas Cons. Commission Anchorage ') DRilliNG FLUID PROGRAM Well KRU 3G-25 Density PV YP Viscosity Initial Gel 10 Minute Gel API Filtrate pH 0/0 Solids Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 50-80· 5-15 15-40 1 0-12 9.5-10 ±100/0 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 toTD 11.1 1 0-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 < 12°k DrillinQ 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 General 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/ft. This shows that formation breakdown would occur before a surface pressure of 1,808 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 3G-25 is 3G-13. As designed, the minimum distance between the two wells would be 11.81 @ 4751. Drilling Area Risks: Risks in the 3G-25 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. 5-1/2" casing will be topset above the Kuparuk and either Nordic Rig #2 or a coiled tubing unit will drill out a 4-3/4" hole, and run a 3-1/2" liner 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 11.1 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 7-5/8" 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 gra~B€c&~ V E D JUN 2 5 1996 "'aske 011 & Gas Cons. Commission Anchor~ga ') ) ANNULAR PUMPING OPERATIONS WELL KRU 3G-25 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. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non- freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 3G-25 surface/production casing annulus will be filled with diesel after setting the production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface, if the surface shoe is within 200' TVD of the top of the hydrocarbons. Alternatively, if the hydrocarbons are far below the shoe then sufficient cement volume will be pumped during the production cement job to cover the formation. It is requested that 3G-25 be permitted for annular pumping occurring as a result of drilling operations, per proposed regulations 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Please reference the enclosed directional drilling plan for other formation markers in this well. A list of all publicly recorded wells within 1/4 mile of the disposal operation is included in this permit application. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The 3G surface casing shoes will be set ±200' vertical below the base of the West Sak into the heart of the shales. The maximum volume of fluids pumped down the annulus of this well will not exceed 35,000 bbls without the specified permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1500 psi, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1500 psi Max Pressure = 3410 psi The surface and production casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 850/0 collapse and burst ratings listed below. OD Wt (in) (Ib/ft) Grade Range 7.625 29.7 L-80 3 5.500 15.5 L-80 3 Conx Type LTC L TC-M Collapse (psi) 4790 4990 850/0 of Collapse 4072 4242 Burst (psi) 6890 7000 850/0 of Burst 5857 5950 Fluids to be disposed of in subject annulus will be limited to drilling wast~~(;ttdJk6 Dth drilling a well as defined in 20 MC 25.080 (g) (1) & (2). JUN 2 5 1996 Alaska 011 & Gas Cons. Commission Anchorage --..,<o.¡/:ft ": ,';~:~~f{~~' ~ \':~~.~ ~ ) ARca ALASKA, Inc. Pad 3G 25 slot #25 Kuparuk River Unit North Slope, Alaska C LEA RAN C ERE paR T by Baker Hughes INTEQ Your ref : 25 Version #4 OUr ref : prop1584 License Date printed : 29-May-96 Date created : 26-Mar-96 Last revised: 29-May-96 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 23 12.884,w150 0 47.469 Slot location is n70 22 47.923,w150 0 46.884 Slot Grid coordinates are N 5988560.329, E 498398.232 Slot local coordinates are 2538.00 S 20.00 E Reference North is True North Object well path Main calculation performed with 3-D Minimum Distance method PGMS <0-9940'>,,24,Pad 3G PGMS <0-103221>,,9,Pad 3G PGMS <0-96531>,,16,Pad 3G PGMS <0-97821>,,22,Pad 3G PGMS <0-7795I>,,17,Pad 3G PGMS <0-9650'>,,18,Pad 3G PGMS <0-8200'>,,19,Pad 3G PGMS <0-10100'>,,20,Pad 3G PGMS <0-116991>,,21,Pad 3G PGMS <0-7420'>,,23,Pad 3G PGMS <0-6900'>,,11,Pad 3G PGMS <0-8089I>,,4,Pad 3G PGMS <0-67491>,,12,Pad 3G PGMS <0-7040'>,,14,Pad 3G PGMS <0-66591>,,2,Pad 3G PGMS <0-82191>,,5,Pad 3G PGMS <0-7910'>,,6,Pad 3G PGMS <0-87671>,,7A,Pad 3G PMSS <5700-87671>,,7,Pad 3G PGMS <0-87591>,,8,Pad 3G PGMS <0-8250'>,,10,Pad 3G PMSS <0-9320'>,,13,Pad 3G PMSS <0-7990'>,,15,Pad 3G 3 Version #4,,3,Pad 3G Closest approach with 3-D minimum distance method Last revised Distance M.D. Diverging from M.D. 15-May-91 248.5 2040.0 2040.0 15-May-91 150.2 60.0 7360.0 14-May-91 82.8 500.0 7480.0 15-May-91 238.5 500.0 6820.0 14-May-91 112.3 650.0 2180.0 14-May-91 140.0 100.0 7320.8 20-Jun-91 158.8 650.0 7240.5 15-May-91 190.1 100.0 120.0 15-May-91 215.2 60.0 7240.5 15-May-91 265.1 60.0 450.0 14-May-91 99.0 325.0 325.0 14-May-91 273.2 350.0 7360.0 14-May-91 74.5 325.0 7480.0 14-May-91 37.3 550.0 550.0 14-May-91 325.0 120.0 120.0 14-May-91 250.0 100.0 6820.0 20-Jun-91 225.1 60.0 7240.5 15-May-91 199.4 325.0 325.0 15-May-91 199.4 325.0 325.0 14-May-91 175.2 60.0 7093.1 14-May-91 125.1 100.0 120.0 14-May-91 11.8 475.0 475.0 14-May-91 56.7 625.0 625.0 29-May-96 300.0 300.0 300.0 Created by : jone$ ._._.~-----_....~,_....- ARca ALASKA, Structure : Pad 3G Well 25 Inc. Field : Kuparuk River Unit Location: North Slope. Alaska For: D PETRASH Date plotted : 29-Moy-96 Plot Reference Is 25 Version '4. Coordinates are In feet reference slot '25. '~,"rlI~' ""~"'= "'" ("",,, ",,) I~ 400 _ 0 0 ci 0 N 0 - ~ 400 _ 0 ü (.f) 800 _ 1200_ ....c -+- 1600_ 0.. Q) 0 2000_ 0 2400_ Ü -+- 2800_ L () > 3200_ () ::> 3600_ L r- 4000_ I I 4400 _ V 4800_ 5200_ 5600_ 6000_ 6400 TO LOCATION: 1550' FSL, 1780' FEL SEC. 14, T12N, R8E 2100 1800 Top Unit A K-l Marker TARGET LOCATION: RKB ELEVATION: 94' 1334' FSL, 1685' FEL SEC. 14, T12N, R8E KOP NO=300 TMO=300 DEP=O · 3.00 · 6.00 · 9.00 12.00 15.00 18.00 BUILD 3 DEG / 100' 21.00 24.00 27.00 30.00 33.00 36.00 39.00 EOC ND= 1571 TMO= 1690 DEP=484 81 PERMAFROST ND=1594 TMD=1721 DEP=505 TI UGNU SNOS TVD=1744 TMD=1922 DEP=639 TARGET lVD=5774 TMD=7321 DEP=4230 NORTH 3872 WEST 1705 T/ W SAK SNDS NO=2469 TMD=2894 OEP=1285 < West Scale 1 : 150.00 1500 600 300 o 300 1200 900 _4200 _3900 _3600 N 23.76 DEG W _3300 4230' (TO TARGET) _3000 _2700 ^ _2400 ~ ~ _2100 Z _1800 0 , _1500 -+ :J _1200 _ 900 _ 600 (.f) 0 _ 300 Q iD _ 0 ESTIMATED 01 ~ SURFACE LOCATION: 0 _ 300 0 2538' FNL, 20' FWL SEC. 24, T12N, R8E 8/ W SAK SNDS TVD=2854 TMD=3409 DEP=1628 'þ'\". 7 5/8" CSG PT lVD=3054 TMD=3677 DEP= 1806 COLVILLE SNOS lVD=3194 TMD=3865 DEP=1931 AVERAGE ANGLE 41.71 DEG B/ HRZ lVD=5604 TMD=7093 DEP=4079 TARGET - T/ UNITS DIC TVD=5774 TMD=7321 DEP=4230 B/ KUP SNDS TVD=5890 TMD=7476 DEP=4334 TD - ~ CSG PT TVD=6039 TMD=7676 DEP=4467 4111." 400 Scale I o I 3600 I 400 I 800 I 1200 I 1600 I 2000 I 2400 I 2800 I 3200 : 200,00 Vertical Section on 336.24 azimuth with reference 0.00 N, 0.00 E from slot I 4000 "I./:> 'jlli' l' 4'I%,fl '\/t>:..C; 12.1 TMb,: -¡ Z? , ~ K-1 MARKER TVD=5714 TMD=7240 DEP=4177 T/ UNIT A ROte ti'1tU4255 þ '\". JUN 2 5 1996 I I 4400 4800 Alaska 011 & Gas Cons. Commission #25 Anchorage ARca ALASKA, Inc. Structure : Pad 3G Well :25 Created by : joneo For: D PETRASH Field : Kuparuk River Unit Location North Slope. Alaska Dote plotted : 29-~ay-96 Plot Reference I, 25 Veralon 14. COOI"dlnate, ore In feet reference slot (125. True Vertical Depth' ore r<Jfer"nçe RKB (Parker 12<45). == <- West Scale : 20.00 ,~ 400 360 320 280 240 200 160 120 80 40 0 40 80 120 680 I I 680 f3 640_ _640 600_ _600 560_ _560 520_ .2100 _520 480_ _480 440_ _440 400_ _400 ^ ^ I 360_ _360 I I I 320_ . 1900 _320 £ Z -I- 280_ _280 a L- a , 240_ _240 -+- Z :::r 200_ _200 1700 . 160_ 120_ _120 80 _ _ 80 40_ _ 40 0 (/) q () 0 ""t:S> 9- N (!) 0 - _ 0 cw--- (l) N "6 40_ _40 0 u 0 (f) 0 I I I I I I 400 360 320 280 240 200 160 120 0 40 120 <- West Scale : 20.00 ) ) kUPARUK RIVER UNIT 20" DIVERTER SCHEMATIC ---.J L- 6 DO NOT SHUT IN DIVERTER ~ L AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. 5 4 MAINTFNANCE & OPFRATION 1. UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND 3 THAT THE VALVE OPENS IMMEDIATELY. 2. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN I ~ INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. I~ OPEN VALVE TO ACHIEVE DIVERSION. \ 2 ! 6...J 1 ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM ASA VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR. 2. SLlP-QN 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. DKP 1119194 ~ ) L- 7 2 S < < < 6 5 4 3 \ 2 \ 1 I V ) 13 5/811 5000 PSI BOP STACK ACCUMULATOR CAPACITY TFST > > 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OFTHE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST > 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. 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. ALL OTHERS 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, LINES, 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 BOTTOM 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 BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING 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 DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. VBRS WILL ACCOMODATE 3-112" TO 5-1/2" OR 5" TO 7" PIPE ODS AS APPROPRIATE. R E C E \ V E D JUN 2 {; 1996 ~\aska on &. Gas Cons. comm\ss\OO M Anchorage RECf\VED JUN ? " 1996 torom\ss\on - 0\\ & G~S r()f'\S A\aska A.nc"m age 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-518" - 5000 PSI SPACER SPOOL 4. 13-518" - 5000 PSI PIPE RAMS 5. 13-518" - 5000 PSI DRLG SPOOL WI CHOKE AND KILL LINES 6. 13-518" - 5000 PSI DOUBLE RAM WI PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR il. WELL PERMIT CHECKLIST COMPANY /'!f,-¿.n WELL NAME ¡!;/?J.1 sC:2 f; PROGRAM: exp 0 dev 0 re:r.1 0 serv 0 weilbore seg D '!œ2: dìSPOsa~ req .à FIELD&POOL c..¡7d/LX:? INITCLASS /ÞA/ /....ð// GEOLAREA lr7rJ UNIT# j)/hD ON/OFFSHORE ð - " ADMINISTRATION I! II I I " Ii P ,! Ii WØð6 ENGINEERING APf~ __ DtJE <..J:I 6¡ ~1 GEOLOGY ~ 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . . y. N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number.. . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool. . . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drlg unit boundary. . . . . .Y N 6. Well located proper distance from other wells. . . . . . . . . . Y N 7. Sufficient acreage available in drilling unit. . . . . . . . . . . . Y N 8. If deviated, is wellbore plat included. . . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 1 O. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order . . . . . . . Y N 12. Permit can be issued without administrative approval. . . . . Y N 13. Can permit be approved before 15-day wait . . . . . . . . , Y N \J REMARKS 14. Conductor string provided . . . . . . . . . . . . . . . . . . .~N 15. Surface casing protects all known USDWs . . . . . . . . .. N 16. CMT vol adequate to circulate on conductor & surf csg . . . N 17. CMT vol adequate to tie-in long string to surf csg . . . . . . . Y (Ñ) 18. CMT will cover all known productive horizons. . . . . . . . . ~¥ 19. Casing designs adequate for C, T, B & permafrost. . . . .. N 20. Adequate tankage or reserve pit. . . . . . . . . . . . . . . . N 21. If a re-drill, has a 10-403 for abndnmnt been approved. . . . Y N- 22. Adequate well bore separation proposed. . . . . . . . . . . . ~ N 23. If diverter required, is it adequate. . . . . . . . . . . . . . . . N 24. Drilling fluid program schematic & equip list adequate. . . . N 25. BOPEs adequate. . . . . . . . . . . . . . . . . . . . . . . . N 26. BOPE press rating adequate; test to 3 0l>D psig. N 27. Choke manifold complies w/API RP-53 (May 84). . . . . . 28. Work will occur without operation shutdown. . . . . . . . . . 29. Is presence of H2S gas probable . . . . . . . . . . . . . . . R~Jd.-~ I~ g{ Z 0 H - <-. ~ H H ~ H Z H - ....... H (JJ (JJ '1:: > CJ ~ J 30. Permit can be issued w/o hydrogen sulfide measures. . . . . Y 31. Data presented on potential overpressure zones. . . . . . . Y 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 33. Seabed condition survey (if off-shore) . . . . . . . . . .. . Y ?JYß ~.£~ 34. Contact name/phone for weekly progress reports . .. ... Y /(/f j r.A" /7Jð Lexpfofãtoï¡ only] HOWlljb - A:'FORM5'chekiist rrN 4J96 GEOLOGY: RP~-I ENGINEERING: COMMISSION: BE~ -rj2!96 DWJ Qr" JDH <1f!- JON TAB~ Commentslinstrucüons: , /. ~ ~~~ort- ~~) ~~J1 Ú;r' * ~ 1> to-rf~-:;.~ r4~'7 (j .