ML11083A025

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Lr Hearing - Latest Slides
ML11083A025
Person / Time
Site: Indian Point  Entergy icon.png
Issue date: 03/03/2009
From: Kimberly Green
Division of License Renewal
To: Stroud M
Entergy Nuclear Operations
References
Download: ML11083A025 (49)
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Text

Stuyvenberg, Andrew From: Kimberly Green Sent: Tuesday, March 03, 2009 1:36 PM To: STROUD, MICHAEL D

Subject:

latest slides Attachments: ACRS-Indian Point-Presentation 03-03-09.ppt Here are the latest. I don't expect too many changes at this point.

Kim 1

Advisory Committee on Reactor Safeguards License Renewal Subcommittee Indian Point Nuclear Generating Unit Nos. 2 and 3 Safety Evaluation Report with Open Items March 4, 2009 Kimberly Green, Project Manager Office of Nuclear Reactor Regulation

Introduction

  • Overview
  • Section 2: Scoping and Screening Review
  • Section 4: Time-Limited Aging Analyses (TLAAs)
  • Open Items 2

Overview

  • LRA Submitted by letter dated April 23, 2007
  • Westinghouse 4 4-Loop Loop
  • 3216 MWth, 1080 MWe
  • Operating license DPR-26 DPR 26 (IP2) expires September 28, 2013
  • Operating license DPR-64 (IP3) expires December 1212, 2015
  • Located approximately 25 miles north of NYC limits 3

Overview

  • Safety Evaluation Report with Open Items was i

issued d JJanuary 15 15, 2009

  • 20 Open items
  • 272 Audit Questions
  • 38 Commitments 4

Overview

  • Scoping and Screening Methodology Audit

- October 8, 2007 - October 12, 2007

- August 27, 2007 - August 31, 2007

- OOctober t b 22, 22 2007 - October O t b 26,26 2007

- November 27, 2007 - November 29, 2007

- February 19, 2008 - February 21, 2008

  • Regional eg o a License ce se Renewal e e a Inspections spect o s

- January 28, 2008 - February 1, 2008

- February 11, 2008 - February 14, 2008

- March 31, 2008 - April 2, 2008

- J June 2 2008 - June 2, J 6 6, 2008 2008, and d JJune 18 18, 2008 5

Open Items

  • SER issued with 20 open items

- 14 with requests for additional information

- 6 are still under review by staff

  • Applicant submitted additional information dated January 27, 2009
  • Staff can close out 13 Open Items 6

Section 2: Structures and Components Subject to Aging Management Review Section 2.1 - Scoping and Screening Methodology

  • Based on audit and review staff concluded that the applicants methodology is consistent with the requirements of 10 CFR 54.4 and 54.21(a)(1)

Section 2.2 - Plant-Level Scoping Results

  • IP2 chlorination and IP3 H2 systems initially omitted from scope

7

Section 2.3 - Scoping and Screening Results:

Mechanical Systems

  • Mechanical Systems: 59 (IP2 ) and 87 (IP3)
  • Two Tier Review of Balance of Plant systems:

- Tier 1 Review: Review LRA and UFSAR

- Tier 2 Review: Detailed review of LRA, UFSAR, and li license renewall d drawings i

  • 100% of mechanical systems identified by applicant as within the scope of license renewal were reviewed 8

Section 2.3 - Scoping and Screening Results:

Mechanical Systems

  • Staff identified omission of nonsafety-related components from scope for IP2 containment spray
  • Applicant re re-evaluated evaluated and identified 3 other systems (IP2 CCW, IP3 CCW, and IP3 BVS)
  • Amended LRA and added components to scope 9

Section 2.3 - Scoping and Screening Results Mechanical Systems

  • Three Open Items

- OI 2 2.3A.3.11-1 3A 3 11 1 - yard hose houses and chamber housings

- OI 2.3.4.2 feedwater isolation valves

- OI 2.3A.4.5 auxiliary feedwater pump room fire event systems

  • These OIs can be closed 10

Section 2.4 - Scoping and Screening Results:

St Structures t

  • Staff concluded that there were no omissions of structures t t or structural t t l components t from f scope of license renewal in accordance with 10 CFR 54 4(a) and no omissions from AMR in 54.4(a),

accordance with 10 CFR 54.21(a)(1).

11

Section 2.5 - Scoping and Screening Results:

Electrical and Instrumentation and Control Systems

  • OI 2.5 Station blackout scoping
  • Issue is under staff evaluation
  • With exception of SBO OI scoping, staff concluded no omissions of electrical and instrumentation and control system components from the scope of license renewal in accordance with 10 CFR 54.4(a),

54 4(a) and no omissions from AMR in accordance with 10 CFR 54.21(a)(1) 12

Section 2.6 - Conclusion for Scoping and Screening

54 4(a) and those SCs subject to an AMR in accordance with 10 CFR 54.21(a)(1).

13

License Renewal Inspections Glenn Meyer Region I Inspection Team Leader

Inspection p Objectives j

  • Scoping of Non-safety SSCs
  • Followup:

o o up IP2 SBOS O DG,G, electrical e ect ca cab cable e

vault, and containment liner 15

Scoping

  • Scoping of non-safety SSCs - generally accurate and acceptable
  • Structural and spatial interactions reviewed
  • AMP reviews i ffound d 2 componentt scoping i

errors 16

Aging g g Management g Program g Review Resolved by LRA Amendment 3:

  • Structural Monitoring
  • Oil Analysis
  • Diesel Fuel Monitoring
  • Water W t Chemistry Ch i t
  • Metal-Enclosed Bus Inspection 17

Aging g g Management g Program g Review Resolved by LRA Amendment 3:

  • Selective Leaching
  • Non-EQ N EQ B Bolted l dC Cable bl CConnections i

Resolved by LRA Commitment 37:

  • Exposed rebar on containment exterior 18

Aging g g Management g Program g Review Resolved Onsite:

  • Metal-Enclosed Bus Operating Experience
  • Instrument air heat exchangers g
  • AMR for transite material
  • Condition Reports on isolated degradation 19

Follow Up p Inspections p

  • IP2 SBO diesel - scoping and system review when operational
  • Electrical cable vault - when accessible
  • Unit 2 containment liner - when accessible 20

Inspection p Conclusions

  • Inspection results support a conclusion of reasonablebl assurance that th t aging i effects ff t will be managed and intended functions will ill b be maintained i t i d 21

Current Performance

  • Both units - Licensee Response Column
  • All Findings - Green
  • All Performance Indicators (PIs) - Green 22

Section 3: Aging Management Review R

Resultslt

  • Section 3.1 - Reactor Vessel & Internals
  • Section 3.2 - Engineered Safety Features
  • Section 3.3 - Auxiliary Systems
  • Section 3.4 - Steam and Power Conversion System
  • Section 3.5 - Containments, Structures and Component Supports
  • Section 3 3.6 6 - Electrical and Instrumentation and Controls System 23

Section 3.0.3 - Aging Management Programs (AMP )

(AMPs)

- 10 New Programs

- 31 Existing Programs

  • 15 consistent with GALL Report
  • 10 consistent with GALL Report with enhancements
  • 8 had exceptions
  • 8 plant-specific 24

Section 3.0.3 - AMPs

  • 8OOpen Items It
  • The following 5 OIs can be closed

- OI 3.0.3.2.7 fire penetration seals

- OI 3.0.3.3.3 acceptance criteria for visual examinations

- OI 3.0.3.3.4 inspection methods, etc. for lubrite sliding supports

- OI 3.0.3.3.4 corrective actions for ISI

- OI 3.0.3.3.7 Periodic Surveillance and Preventive Maintenance Program 25

Section 3.0.3 - AMPs

  • The following 3 OIs are still under review

- OI 3.0.3.2.15 IP2 reactor refueling cavity leakage

- OI 3.0.3.2.15 IP2 spent fuel pool leak

- OI 3.0.3.3.2 Exterior containment concrete degradation 26

Section 3.1 - Aging Management of Reactor Vessel, Internals, and RCS

  • 2 Open p Items

- OI 3.1.2 Nickel alloy components

- OI 3.1.2.2.7 3 1 2 2 7-1 1 - Inspection of CASS These 2 OIs can be closed 27

Section 3.3 - Aging Management of Auxiliary Systems

  • OI 3.3 3 3-1 1 - Clarification of material/environment/aging effect for titanium components This OI can be closed 28

Section 3.4 - Aging Management of St Steam and d Power P C Conversion i Systems

  • One Open Item

- OI 3.4 AMR results for a fire in IP2 auxiliary ili ffeedwater d t pump room This OI is still under staff review 29

Section 3.5 - Aging Management of C t i Containments, t Structures St t and d Component Supports

  • 3 Open Items
  • These 2 OIs are still under staff review

- OI 3.5-1 3 5 1 - Water-cement W t t ratio ti for f IP concrete t

- OI 3.5 Reduction of strength and modulus of concrete due to elevated temperatures 30

Section 3.5 - Agingg g Management g of Containments, Structures and Component Supports

  • This OI can be closed

- OI 3.5 Aging management of concrete surrounding B1 supports 31

Section 3.6 - Aging Management of Electrical and I&C Systems

  • LRA identified no aging effects for IP2 138-kV hi h lt high-voltage cable bl
  • Staff issued RAI
  • Applicant A li t amended d d LRA tto add dd cable bl tto Periodic Surveillance and Preventive Maintenance Program g

32

Section 33.77 Conclusion With the exception of the Open Items, the applicant li t has h d demonstrated t t d that th t aging i

effects will be adequately managed during the period of extended operation in accordance with 10 CFR 54.21(a)(3) 33

Section 4: Time-Limited Aging g g Analyses y

  • 4.1 Identification of Time Limited Aging Analyses (TLAAs)
  • 4.2 Reactor Vessel Neutron Embrittlement
  • 4.3 Metal Fatigue
  • 4.4 Environmental Qualification of Electrical Equipment
  • 4.5 Concrete Containment Tendon Prestress
  • 4.6 Containment Liner Plate and Penetration Fatigue
  • 4.7 Other Plant-Specific TLAAs 34

Section 4.2: Reactor Vessel Neutron Embrittlement - Upper Shelf Energy Limiting Beltline MaterialLower Shell Plate (B2002-3)

Unit 2

% CU 48 EFPY Fluence Initial Charpy V Irradiated Acceptance

((E>1 MeV)) at notch USE Value Charpy V Criterion per 1/4T (ft-lb) notch USE 10 CFR 50, 1019 (n/cm2) Value at App. G 48 EFPY (ft-lb) (ft-lb) 0.25 1.136 74 48.3 >50

Section 4.2: Reactor Vessel Neutron Embrittlement - Upper Shelf Energy Limiting Beltline MaterialLower Shell Plate (B2803-3)

Unit 3

% CU 48 EFPY Fluence Initial Charpy V Irradiated Acceptance

((E>1 MeV)) at notch USE Value Charpy V Criterion per 1/4T (ft-lb) notch USE 10 CFR 50, 1019 (n/cm2) Value at App. G 48 EFPY (ft-lb) (ft-lb) 0.24 0.9298 68 49.8 >50

Section 4.2: Reference Temperature for Pressurized Thermal Shock (PTS) Values Limiting Beltline MaterialLower Shell Plate (B2803-3)

Unit 3

%CU 48 EFPY Fluence Initial Charpy RTPTS Acceptance

%Ni (E>1 MeV) RTNDT 0F Criterion per

(@clad/steel interface) 0F 10 CFR 50.61 1019 (n/cm2) 0F 0.24 1.56 74 279.5 <270oF 0.52 Commitment 32: As required by 10 CFR 50.61(b)(4), IP3 will submit a plant-specific safety analysis for plate B2803-3 B2803 3 to the NRC three years prior to reaching the RTPTS screening criterion. Alternatively, the site may choose to implement the revised PTS rule when approved. 37

Section 4.3: Metal Fatigue g Analysesy

  • 60-year fatigue analyses were performed for all NUREG/CR-6260 locations, except 2 locations (IP2) and 3 locations (IP3)

38

Section 4.3: Metal Fatigue g Analyses y Section 4.3 - Class 1 Fatigue g

  • One Open Item

- OI 4.3-1 4 3 Number of IP3 plant heatups and cooldowns This OI can be closed 39

Open Items Still Under Staff Review

  • OI 3.0.3.2.15 IP2 reactor refueling cavity leakage
  • OI 3.0.3.2.15 IP2 spent fuel pool leak
  • OI 3.0.3.3.2 Exterior containment concrete d

degradation d ti

  • OI 3.5 Water-cement ratio for IP concrete
  • OI 3.5 Reduction of strength and modulus of concrete due to elevated temperatures 40

- Applicant revised LRA Figures 2.5-2 and 2.5-3, the Offsite Power Scoping Diagram(s) for IP2 and IP3 for primary primar and secondar secondary offsite po powerer paths

- By letters dated March 24, 2008 and August 14, 2008,, the applicant pp revised and clarified its response p

- The staff is completing its review of the applicants information on the SBO scoping boundary and will d

document t its it conclusion l i iin ththe fifinall SER 41

  • OI 3.0.3.2.15 IP2 reactor refueling cavity leakage

- IP2 ref refueling eling ca cavity it leaks at the upper pper ele elevations ations of the stainless steel cavity liner when flooded during refueling outages

- Attempts have been made to mitigate this condition

- An action plan is being developed for permanent fix

- Applicant has committed to perform one-time inspection prior to entering period of extended operation to confirm absence of degradation (Commitment 36)

- Applicant has not identified augmented inspections for period of extended operation

- Staff sent draft RAI to request how the AMP will monitor condition during period of extended operation 42

  • OI 3.0.3.2.15 IP2 spent fuel pool leak

- IP2 spent fuel pool (SFP) has experienced leakage

- IP2 SFP does not have leak chase channels

- Applicant committed to test the groundwater outside IP2 SFP every 3 months (Commitment 25)

- Applicant pp does not p plan to p perform augmented g

inspections of SFP during the period of extended operation.

- Staff St ff sentt draft d ft RAI to t requestt how h the th AMP will ill monitor this condition during period of extended operation 43

  • OI 3.0.3.3.2 Exterior containment concrete degradation

- External surfaces of IP2 and IP3 containments have locations of concrete spalling

- Applicant explained that areas of spalling occur at cadweld sleeves and scaffolding anchor locations

- Applicant concluded there is sufficient design margin for exposed rebar

- Applicant committed to perform enhanced inspections of containment (Commitment 37)

- Staff sent draft RAI requesting information on how the applicant will use the above within its Containment Inservice Inspection Program 44

- Applicant stated that systems are continuously in operation and monitored

- Applicant stated aging related degradation that occurs during 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> is negligible

- Applicant pp concluded that there are no aging g g effects; therefore no AMPs are necessary

- Applicant provided additional information on January 27, 2009

- Staff is still evaluating applicants applicant s response 45

  • OI 3.5 Water-cement ratio for IP concrete

- LRA identified the water-cement ratios for IP concrete

- Staff identified a discrepancy and asked for clarification

- Applicant stated it used Method 2 in ACI 318-63 318 63 standard to determine concrete strength

- Staff sent draft RAI to define water-cement ratios and provide results of original concrete strength tests tests. Alternatively Alternatively, the applicant may identify applicable aging effects and how they will be managed 46

  • OI 3.5 Reduction of strength and modulus of concrete due to elevated temperatures p

- LRA stated concrete surrounding IP2 penetrations can reach 250 °F

- GALL Report recommends further evaluation to manage reduction of strength and modulus of concrete structures due to elevated temperature (>200 °F)

- Applicant concluded that reduction of strength and modulus is not an aging effect requiring management

- Applicant determined a reduction in strength of 15% from elevated temperatures which is acceptable

- Staff sent draft RAI about how strength margin was determined and if reduction in modulus of elasticity was considered considered. Alternatively Alternatively, the applicant may explain how the aging effect will be managed 47

Questions?

48

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