ML092150687

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Lr Hearing - IPEC-ACRS--draft.ppt
ML092150687
Person / Time
Site: Indian Point  Entergy icon.png
Issue date: 03/02/2009
From:
- No Known Affiliation
To:
Division of License Renewal
References
Download: ML092150687 (41)
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Text

1 IPRenewal NPEmails From:

STROUD, MICHAEL D [MSTROUD@entergy.com]

Sent:

Monday, March 02, 2009 2:27 PM To:

Green, Kimberly

Subject:

IPEC-ACRS--draft.ppt Attachments:

IPEC-ACRS--draft.ppt

Hearing Identifier:

IndianPointUnits2and3NonPublic_EX Email Number:

1491 Mail Envelope Properties (A79A58994C541C48BBCFB319610763CB05006EA1)

Subject:

IPEC-ACRS--draft.ppt Sent Date:

3/2/2009 2:26:54 PM Received Date:

3/2/2009 2:38:35 PM From:

STROUD, MICHAEL D Created By:

MSTROUD@entergy.com Recipients:

"Green, Kimberly" <Kimberly.Green@nrc.gov>

Tracking Status: None Post Office:

LITEXETSP002.etrsouth.corp.entergy.com Files Size Date & Time MESSAGE 0

3/2/2009 2:38:35 PM IPEC-ACRS--draft.ppt 2034240 Options Priority:

Standard Return Notification:

No Reply Requested:

No Sensitivity:

Normal Expiration Date:

Recipients Received:

Indian Point Energy Center Indian Point Energy Center (DRAFT)

(DRAFT)

ACRS License Renewal Subcommittee March 4, 2009 1

Indian Point Energy Center Indian Point Energy Center Personnel in Attendance Personnel in Attendance Joe Pollock Vice President, Site - IP Fred Dacimo Vice President, License Renewal - IP Pat Conroy Director, NSA John McCann Director, Licensing Don Mayer Director Emergency Planning Don Mayer Director, Emergency Planning Rich Burroni Manager, Programs and Components Garry Young Manager, License Renewal y

g g

Tom McCaffrey Manager, Design Engineering John Curry Project Manager, License Renewal - IP Mike Stroud Project Manager, License Renewal Alan Cox Technical Manager, License Renewal Bob Walpole Manager Licensing 2

Bob Walpole Manager, Licensing Rich Drake Supervisor, Civil/Structural Engineering Nelson Azevedo Supervisor, Code Programs

Agenda

  • Background
  • Background
  • Operating History Major Plant Impro ements
  • Major Plant Improvements
  • Scoping Discussion A

li ti f NUREG 1801

  • Commitment Process
  • Topics of Interest
  • Questions 3

IPEC Site Description Westinghouse NSSS UE&C (AE) - WEDCO (Constructor)

IP2 - Westinghouse low pressure turbines, Siemens HP g

p turbine, GE generator IP3 - ABB low pressure turbines, Siemens HP turbine, Westinghouse generator g

g PWR, large dry containment 3216 MWt thermal power p

1078 MWe - IP2, 1080 MWe - IP3 Once-through cooling from Hudson River IP2 dual speed circulating water pumps with Ristroph screens IP3 variable speed circulating water pumps with Ristroph screens 4

Staff complement: approximately 1100

IPEC Operating History Indian Point Unit 2

  • Construction permit October 14, 1966
  • Operating license September 28, 1973 p

g p

  • Commercial operation August 1, 1974
  • Uprated power licenses
  • Uprated power licenses 11.4% (3071 MWt)

March 7, 1990 1 4% (3114 MWt)

M 22 2003 1.4% (3114 MWt)

May 22, 2003 3.26% (3216 MWt)

October 28, 2004 5

IPEC Operating History IPEC Operating History Indian Point Unit 3

  • Construction permit August 13, 1969
  • Operating license December 12, 1975 p

g

  • Commercial operation August 30, 1976
  • Uprated power licenses
  • Uprated power licenses 10.0% (3025 MWt)

August 18, 1978 1 4% (3067 MWt)

N b

26 2002 1.4% (3067 MWt)

November 26, 2002 4.85% (3216 MWT)

March 24, 2005 6

IPEC Operating History IPEC Operating History License Transfers

  • IP3 Con Edison to NYPA December 24, 1975 IP3 NYPA to Entergy November 21, 2000 IP2 Con Edison to Entergy September 6, 2001
  • LR application (IP2 & IP3)

April 23, 2007 pp

(

)

p

  • Operating license expires IP2 September 28 2013

- IP2 September 28, 2013

- IP3 December 12, 2015 7

Major Improvements Major Improvements Indian Point Unit 2 1978 One additional station battery and inverter 1978 One additional station battery and inverter 1981 Fan cooler unit heat exchangers One additional station battery and inverter 1982 Rebuilt control room with human factors and new computers 1985 Dual speed circ pumps & Ristroph screens 1985 Dual speed circ pumps & Ristroph screens 1990 Main generator 1995 Titanium condenser 1996 Implemented 24 month fuel cycle 1997 Converted to best estimate LOCA analysis Replaced NaOH spray additive with 8

Replaced NaOH spray additive with TSP baskets in containment

Major Improvements Major Improvements Indian Point Unit 2 (cont) 1998 Low pressure turbines 1999 Autocatalytic hydrogen recombiners 2000 Steam generators 2000 Steam generators Feedwater heaters Converted to alternate source term Converted to alternate source term 2004 High pressure turbine Moisture separator reheaters p

2006 Main transformers Containment sump improvements 9

2008 SBO / Appendix R diesel generator

Major Improvements Major Improvements Indian Point Unit 3 1981 4th battery charger / inverter 1981 4th battery charger / inverter 1982 Two new fire water tanks and pumps 1983 Fan cooler unit heat exchangers 1984 SBO / Appendix R diesel generator 1985 Variable speed circulating water pumps 1986 Rebuilt control room with new computers 1986 Rebuilt control room with new computers and human factors One main transformer 1987 Titanium condensers 1989 Steam generators Condensate polishing system and blowdown 10 Condensate polishing system and blowdown recovery Feedwater heaters

Major Improvements Major Improvements Indian Point Unit 3 (cont) 1993 L

t bi 1993 Low pressure turbines 1995 Implemented 24 month fuel cycle 1997 Thermal hydrogen recombiners 1997 Thermal hydrogen recombiners 2003 Converted to best estimate LOCA analysis 2005 High pressure turbine g

p Moisture separator reheaters Converted to alternate source term 2007 Second main transformer Containment sump improvements 2008 S

11 2008 Sodium tetraborate baskets

Major Improvements Major Improvements Site 1987 Training building 1997 Water treatment facility 2005 Generation support building 2007 Dry fuel storage IP1 - 160 fuel assemblies IP2 - 96 fuel assemblies 2008 E-plan siren system Planned Emergency operations facility 12

IPEC Plant Status IPEC Plant Status Current Plant Status Both units on-line at full power IP2 continuous days on line - 274 IP3 continuous days on line - 672 Next outages Spring 2009 (IP3)

Spring 2010 (IP2) 13

Indian Point Energy Center 14

IPEC Generation 15

IPEC License Renewal Project IPEC License Renewal Project LRA Development

  • Incorporated lessons learned from previous
  • Incorporated lessons learned from previous applications
  • Peer review conducted - NEI and other Peer review conducted NEI and other utilities
  • LRA internal reviews (Safety Review C

itt d QA)

Committees and QA)

  • LRA prepared by experienced, multi-discipline Entergy team (utilized corporate discipline Entergy team (utilized corporate and on-site resources)
  • All comments resolved prior to submittal 16 p

Application of NUREG-1801 Aging Management Reviews

f AMR li it d

t A

E (

i t t

  • 90% of AMR line items used notes A - E (consistent with NUREG-1801, Rev 1) 17

Application of NUREG-1801 Aging Management Programs

- 31 existing programs

- 10 new programs

- 8 plant-specific programs p

p p

g

- 33 NUREG-1801 programs

Commitment Process

R fi d d i

dit / i ti

- Refined during audit / inspection process

- IP commitment management process

  • Commitment management process established consistent with industry guidance consistent with industry guidance NRC i

l ffi i di ll i t

  • NRC regional office periodically inspects commitment management process 19

Implementation Fleet Approach

  • Employing fleet approach to implementation for Entergy plants that have submitted an LRA License rene al implementation manager named
  • Develop schedule for Entergy plants as renewed licenses approved licenses approved
  • Common fleet programs being developed for Entergy plants gy p 20

SER Open Items SER Open Items Item Status IP2 Fire Protection - yard hose houses y

and chamber housings Closed IP2 & IP3 Main Feedwater System -

stop valves Closed stop valves Closed IP2 Auxiliary Feedwater Pump Room Fire Event Scoping Closed Electrical and Instrumentation & Control Systems - ISG revision NRC review Fire Protection Program - inaccessible g

fire barrier penetration seals Closed Structures Monitoring Program -

IP2 reactor cavity NRC review 21 IP2 reactor cavity NRC review Structures Monitoring Program -

IP2 spent fuel pool NRC review

SER Open Items SER Open Items Item Status Containment Inservice Inspection -

p containment concrete surface degradation NRC review Heat Exchanger Monitoring - visual inspection criteria Closed inspection criteria Closed Inservice Inspection Program - Lubrite sliding supports Closed Inservice Inspection Program -

ASME Code Section XI Closed Nickel Alloy Program - program y

g p

g clarification Closed Inservice Inspection Program -

CASS components Closed 22 CASS components Closed Service Water System - material /

environment clarification Closed

SER Open Items SER Open Items Item Status Periodic Surveillance and Preventive Maintenance - program elements Closed Auxiliary Feedwater Pump Room Fire Event - aging management NRC review Fire Event aging management NRC review Containment Structures -

water-cement ratios NRC review Concrete Structures - ACI 349 long-term temperatures limits NRC review Structures and Component Supports -

p pp Groups B1 - B5 supports Closed Class 1 Fatigue - IP3 heatup and cooldown transients Closed 23 cooldown transients Closed

Topics of Interest

  • Remaining Open Items

- OI 2.5.1 SBO scoping

- OI 3.4-1 AMR results for the auxiliary feedwater pump room event

- OI 3.0.3.2.15-1 IP2 reactor refueling cavity leakage

- OI 3.0.3.2.15-2 IP2 spent fuel pool leak

- OI 3.0.3.3.2-1 Exterior containment concrete degradation

- OI 3.5-1 Water-cement ratio for IP concrete

- OI 3.5-2 Reduction of strength and modulus of concrete due to elevated temperatures

  • Other Topics of Interest

- Reactor vessel integrity

- Buried piping aging management program 24 Buried piping aging management program

- IP2 containment liner - feedwater event

SBO Scoping OI 2.5-1 SBO Scoping SBO scoping for IP2 and IP3 meets the requirements SBO scoping for IP2 and IP3 meets the requirements of 10 CFR 54.4(a)(3)

Th LR SBO b

d i i d

ith The LR SBO recovery boundary is in accordance with the NRC guidance (NUREG-1800, Section 2.1.3.1.3 and 2.5.2.1.1)

The LR SBO recovery boundary is also in accordance with the proposed NRC guidance in LR-ISG-2008-01 (D

ft i d 3/5/2008)

(Draft issued 3/5/2008)

Both primary and alternate sources of offsite power 25 Both primary and alternate sources of offsite power are included for SBO recovery for IP2 and IP3

IP2 Auxiliary Feedwater Pump Room Fire Event OI 3.4-1 Component Aging Management Secondary systems credited for alternate flow path to steam generators for a period of one hour in the lik l t

f fi i

th unlikely event of fire in the room With exception of IP1 CST, normal plant operation directly demonstrates ongoing ability of the identified directly demonstrates ongoing ability of the identified systems to perform license renewal intended function RAI requested additional detail on component types credited and aging management Provided requested information in letter dated January 27 2009 26 27, 2009

Structures Monitoring Program OI 3.0.3.2.15-1 IP2 Reactor Refueling Cavity Structural Integrity g

y Stainless steel liner leakage occurs only during refueling outages since late 1970s. Corrective ti i

l t d ith i

d lt actions implemented with mixed results Evaluation of concrete samples concluded concrete and rebar behind the cavity lining remain capable of and rebar behind the cavity lining remain capable of performing license renewal intended function New processes being researched to repair leaks in the reactor refueling cavity liner Aging management includes SMP inspections, core bore sample of concrete and inspection of rebar 27 bore sample of concrete and inspection of rebar

Structures Monitoring Program 28

Structures Monitoring Program OI 3.0.3.2.15-2 IP2 Spent Fuel Pool

  • Pool liner leakage first identified and repaired in g

p 1992

  • 2005 during excavation for dry fuel storage, an exterior shrinkage crack in concrete wall was found exterior shrinkage crack in concrete wall was found
  • 2007 liner leak found and repaired in transfer canal
  • Structural evaluations concluded that the concrete
  • Structural evaluations concluded that the concrete and rebar remain capable of performing license renewal intended function

Structures Monitoring Program IP2 Spent Fuel Pool 30

Structures Monitoring Program OI 3.0.3.3.2-1 Exterior Containment Concrete Degradation Isolated areas exist at Cadweld joints of rebar and at attachment points used for scaffolding during construction

- First documented during the initial IWL inspection in 1995 Evaluation of structural impact - reinforcing steel provides Evaluation of structural impact reinforcing steel provides most of the strength, observed surface degradation has no impact on ability of containment to perform its intended function function Areas are monitored by Structures Monitoring Program Commitment for program enhancement to better 31 p

g characterize observed degradation through the use of optical aids improving trending capabilities

Structures Monitoring Program OI 3.5-1 Water-Cement Ratio for IP concrete NUREG-1801 identifies loss of material (spalling, scaling) and

( p g,

g) cracking/freeze-thaw as aging effects for concrete in outdoor air environment Recommends evaluation considering water-cement ratio for Recommends evaluation considering water cement ratio for plants with moderate to severe weathering conditions IPEC water-cement ratios for concrete are outside NUREG-1801 recommended range 1801 recommended range ACI 318-63, original design spec for IPEC, provides two methods to determine the required concrete strength IPEC used method 2 for testing of concrete mixtures for containment concrete IPEC actual test reports confirm the compressive strength of 32 IPEC actual test reports confirm the compressive strength of concrete was above the required 3000 psi of ACI 318-63

Structures Monitoring Program OI 3.5-2 Reduction of strength and modulus of concrete due to elevated temperatures Concern that IP2 hot piping penetrations are allowed to operate at temperatures greater than 200o F NUREG 1801 allows local area concrete temperature greater NUREG-1801 allows local area concrete temperature greater than 200o F with a plant specific evaluation IP2 plant specific evaluation for the effects of temperatures up t

250o F f

d to 250o F was performed

  • Engineering evaluations determined that a maximum of 15% reduction in the strength of concrete for temperatures up to 250o F
  • Concrete tests showed actual strengths more than 20%

above design strength of 3000 psi 33 g

g p

Topic of Interest IP2 Reactor Vessel Integrity Vessel was manufactured by Combustion Engineering Limiting Upper Shelf Energy (USE) location is Plate B2002-3 at 48.3 ft-lbs. Although less than the Appendix G screening criteria of 50 ft-lbs, it exceeds the 43 ft-lbs required by the WOG i

l t

i l

i equivalent margin analysis.

Limiting RTPTS location is circ weld 34B009 at 269 4o F which is Limiting RTPTS location is circ weld 34B009 at 269.4 F which is less than the screening criteria of 300o F.

34

Topic of Interest IP3 Reactor Vessel Integrity Vessel was manufactured by Combustion Engineering Limiting Upper Shelf Energy (USE) location is Plate B2803-3 at 49 8 ft lb Alth h thi i l th th A

di G i

49.8 ft-lbs. Although this is less than the Appendix G screening criteria of 50 ft-lbs, it exceeds the 43 ft-lbs required by the WOG equivalent margin analysis.

Limiting RTPTS location is plate B2803-3 at 279.5o F which exceeds the screening criteria of 270o F.

As required by 10CFR50.61, IP3 will submit a plant-specific q

y p

p safety analysis at least three years prior to exceeding the screening criterion 35

Topic of Interest Recent Buried Piping OE

  • As part of the first phase of the inspection, two locations were excavated in Fall 2008. Inspected six pipe sections (i.e. three sections at each location)

I ti l d ti d

d ti

  • Inspections revealed some coating degradation.

Pipe wall thickness measured with UT

  • UT indicated that the corrosion was limited to the
  • UT indicated that the corrosion was limited to the surface since the piping remains at full thickness.
  • The coating was repaired and the holes were 36 e coat g as epa ed a d t e o es e e backfilled.

Topic of Interest Recent Buried Piping OE

  • Recent underground leakage in an 8 condensate line due to external corrosion which led to a through wall defect through-wall defect.
  • The location was excavated, the areas of concern were repaired or replaced and the line was p

p returned to service.

  • A failure analysis is on-going on the removed section of piping to establish additional inspection section of piping to establish additional inspection scope as well as future re-inspection frequency.
  • A five year inspection plan has been developed for 37 the high priority systems

Topic of Interest IP2 Containment Liner 1973 Feedwater Event November 1973 - plant trip from 7% power Flashing steam impinged on the containment liner causing a bulge to develop bulge to develop Piping was repaired, other modifications made, and liner deformation restored leaving a slight permanent deformation During last outage, 2008, visual inspection confirmed liner still in as-left configuration Continuous weld channel pressurization and ILRTs confirm Continuous weld channel pressurization and ILRTs confirm liner integrity Commitment made to perform a one-time bare metal inspection prior to entering the period of extended operation 38 inspection prior to entering the period of extended operation

Comments and Questions 39

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