ML041420110

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Public Meeting Handouts Re Power Uprate License Amendment Request for Seabrook Station Unit No. 1
ML041420110
Person / Time
Site: Seabrook NextEra Energy icon.png
Issue date: 05/20/2004
From:
- No Known Affiliation
To:
Office of Nuclear Reactor Regulation
References
LAR 04-03
Download: ML041420110 (45)
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DRAFT SUPPLEMENTAL INFORMATION ATTACHMENT 1 RESPONSES TO REQUESTS FOR ADDITIONAL INFORMATION FOR LAR 04-03 APPLICATION FOR STRETCH POWER UPRATE

DRAFT SUPPLEMENTAL INFORMATION DRAFT REQUEST FOR ADDITIONAL INFORMATION RELATED TO POWER UPRATE LICENSE AMENDMENT REQUEST SEABROOK STATION DOCKET NO. 50-443 By letter dated March 17, 2004, FPL Energy Seabrook, LLC (Seabrook or the licensee) submitted an amendment request. The proposed amendment would increase the maximum authorized reactor core power level for Seabrook from 3411 megawatt thermal (MWt) to 3587 MWt. This represents a nominal increase of 5.16% rated thermal power.

The U.S. Nuclear Regulatory Commission (NRC) staff has reviewed the information the licensee provided that supports the proposed amendment and requests the following additional information to clarify the submittal:

Based on our review of the licensee's submittal dated March 17, 2004, regarding a request for NRC to approve a stretch power uprate (SPU) for Seabrook, it has been determined that the licensee's submittal needs to be supplemented and documented with the following additional information in order to complete our acceptance review:

Bullet 1:

The submittal should identify those BOP areas (Matrix 5 of RS-001) that are potentially impacted from a safety perspective (including consideration of licensing basis criteria and commitments that have been made) as a result of the proposed SPU, and those that are not impacted (provide explanation for the "no safety impact determination," such as the original design-basis analysis is bounding). This will help to focus NRC review effort and expedite the completion of the review.

+ The SPU evaluation of BOP systems (Matrix 5 of RS-001) should include consideration of all design and licensing basis criteria that apply, including any commitments that have been made. Any instances where the plant licensing basis or commitments are not being satisfied as a result of the SPU should be specifically identified and justified in accordance with 10 CFR 50.59 requirements and the licensee's commitment tracking and control program.

FPL Enersv Seabrook Response:

To address Bullets 1, 2, and 3, Table 1, "Seabrook Station Affected / Unaffected Matrix,"

(below) was prepared to better identify the extent to which systems, components, and analyses are affected by the SPU conditions. The system evaluation process utilized by FPL Energy Seabrook for the SPU required consideration of all design and licensing basis criteria, including any specific commitments. Additionally, the process included interviews with system engineers and a review of system operating and maintenance history. Based on the analyses and evaluations performed for the SPU, the Seabrook Station licensing bases, as revised by the LAR accident analyses (Attachment 1, Section 6.0) and Technical Specification changes (Attachment 2), and applicable commitments are satisfied.

DRAFT SUPPLEMENTAL INFORMATION TABLE 1 SEABROOK STATION AFFE CTED / UNAFFECTED MATRIX LAR 1 .Change To Currcnt System / Component / Affected I Method Of SPU Design Or Licensing Section Evaliiation / Analysis Unaffected' Reconciliation Basis Acceptance Section 3.0 -Design Transients 3.1 NSSS Design Transients Affected Analysis No 3.2 Auxiliary Equipment Design Transients Unaffected J Evaluation No Section 4.0 - Nuclear Steam Supply Systems 4.1.4.1 / Reactor Coolant System Affected Analysis and Evaluation No 4.1.5.1 _ _ _ _ _ _ _ _ _ _

4.1.4.2/ Chemical and Volume Control System Unaffected Evaluation No 4.1.5.2 4.1.4.3 / Residual Heat Removal System Affected Analysis and Evaluation No 4.1.5.3 4.1.4.4 / Safety Injection System Unaffected Evaluation No 4.1.5.4 4.2.3.1 / Main Steam System-NSSS/13OP Interface Unaffected Analysis and Evaluation No 4.2.4.1 (Main Steam Safety Valves, Atmospheric Steam Dump Valves, Main Steam Isolation Valves) .

4.2.3.2 / Steam Dump System-NSSS/13OP Interface Unaffected Analysis and Evaluation No 4.2.4.2 (Steam Dump Valves) 4.2.3.3 / Condensate and Feedwater System-NSSSIBOP Interface Affected Analysis and Evaluation No 4.2.4.3 (Feedwater Isolation Valves, Feedwater Control Valves, Condensate and Feedwater Pump Flow) 4.2.3.4 / Emergency Feedwater System-NSSSIBOP Interface Unaffected Analysis and Evaluation No 4.2.4.4 (Emergency Feedwater Pump Flow, Condensate Storage Tank Inventory)

DRAFT SUPPLEMENTAL INFORMATION TABLE 1 (continued)

SEABROOK STATION AFFECTED / UNAFFECTED MATRIX Change To Current LAR System / Component / Affected I Method or sPu Design Or Licensing Section Evaluation / Analysis Unaffected' Reconciliation Basis Acceptance Criteria Section 4.0 - Nuclear Steam Supply Systems (continued) 4.2.3.5 / Steam Generator Blowdown System-NSSSIBOP Interface Unaffected Evaluation No 4.2.4.5 (Steam Generator Blovwdo1wn Flow) 4.3.1/4.3.2 Reactor Protection System / Affected Analysis No Engineered Safety Features Actuation System 4.3.3.1 Pressure Control Component Sizing Unaffected Analysis No 4.3.3.2 Margin To Trip Analysis Affected Analysis No 4.3.4 Cold Overpressure Mitigation System Unaffected Evaluation No Section 5.0 - Nuclear Steam Supply System Components 5.1.1 Reactor Pressure Vessel Structural Evaluation Affected Analysis and Evaluation No 5.1.2 Reactor Pressure Vessel Neutron Fluence Evaluation Affected Analysis No 5.1.3 Reactor Pressure Vessel Integrity - Neutron Irradiation Affected Analysis No 5.2.5 Thermnl-I-Iydraulic Evaluations of Reactor Internals Affected Analysis No 5.2.6 Mechanical Systems Evaluations of Reactor Internals Affected Analysis No 5.2.7 Structural Evaluation of Reactor Internal Components Affected Analysis and Evaluation No 5.2.8 Reactor Pressure Vessel Internals I-Teat Generation Rates Affected Analysis No 5.3 Fuel Assembly Structural Analysis Affected Analysis No 5.4 Control Rod Drive Mechanisms Affected Analysis and Evaluation No 5.5 Reactor Coolant Loop Piping and Supports Affected Analysis No 5.6 Pressurizer Affected Analysis No 5.7.1 Steam Generator Thermal-Hydraulic Evaluation Affected Analysis No 5.7.2 Steam Generator Structural Affected Analysis No

DRAFT SUPPLEMENTAL INFORMATION TABLE 1 (continued)

SEABROOK STATION AF'1;,ECTED / UNAFFECTED MATRIX l Changc To Current LAR System / Component/ Affected I Method Of SPU Design Or Licensing Section Evaluation / Analysis Unaffected' Reconciliation Basis Acceptance Criteria Section 5.0 - Nuclear Steam Supply System Components (continued) 5.7.3 Steam Generator Design Pressure Unaffected Analysis No 5.7.4 Steam Generator Hardware Evaluation Affected Analysis No 5.7.5 Tube Vibration and Wear Affected Analysis No 5.7.6 Tube Repair Limits (Regulatory Guide 1.121 Analysis) Affected Analysis and Evaluation No 5.7.7 Steam Generator Tube Integrity Considerations Affected Analysis and Evaluation No 5.8.1 Reactor Coolant Pumps (Structural) Affected Analysis No 5.8.2 Reactor Coolant Pump Motors Affected Analysis No 5.9.3.1 Auxiliary System Tanks Unaffected Evaluation No (Chemical and Volume Control, Residual Heat Removal, and Emergency Core Cooling Systems) 5.9.3.2 Auxiliary System Heat Exchangers Unaffected Analysis and Evaluation No 5.9.3.3 Auxiliary System Pumps Unaffected Evaluation No 5.9.3.4 Auxiliary System Valves Unaffected Evaluation No 5.10 Bottom Mounted Instrumentation Affected Analysis No 5.11 Materials Unaffected Evaluation No 2 5.12 Application of Leak-Before-Break Methodology Unaffected Analysis No Section 6.0 - Accident Analysis 6.1.1 l Best-Estimate Large Break LOCA Affected Analysis and Evaluation No 6.1.2 Small Break LOCA Affected Analysis No 6.1.3 JPost-LOCA Subcriticality and Long Term Core Cooling Affected Analysis No Section 6.0 - Accident Analysis (continued) 6.1.4 Containment Sump ply Control I Affected I Analysis No

DRAFT SUPPLEMENTAL INFORMATION TABLE 1 (continued)

SEABROOK STATION AFi,-ECTED / UNAFFECTED MATRIX Change To Current LAR System / Component / Affected I Metlhod Of sPu Design Or Licensing Section Evaluation / Analysis Unaffected' Reconciliation Basis Acceptance Criteria 6.1.5 Hot LCg Switchover Affected Analysis No 6.1.6 Post-LOCA Hydrogen Generation Affected Analysis No 6.1.7 LOCA Hydraulic Forces Affected Analysis No 6.2 Steam Generator Tube Rupture Affected Analysis No 6.3.2.1 Excessive Heat Removal Due to Feedwater System Affected Analysis No Malfunctions 6.3.2.2 Excessive Increase in Secondary Steam Flow Affected Evaluation No 6.3.2.3 Inadvertent Opening of a Steam Generator Dump, Relief, or Unaffected Evaluation No Safety Valve 6.3.2.4 Steam System Piping Failure Affected Analysis No 6.3.3.1 Loss of External Load / Turbine Trip Affected Analysis No 6.3.3.2 Loss of Normal Feedwater Affected Analysis No 6.3.3.3 Loss of Nonemergency AC Power to the Plant Auxiliaries Affected Analysis No 6.3.3.4 Feedwater System Pipe Break Affected Analysis No 6.3.4.1.2 Complete Loss of Forced Reactor Coolant Flow Affected Analysis No 6.3.4.1.1 Partial Loss of Reactor Coolant Flow Affected Analysis No 6.3.4.2 Reactor Coolant Pump Locked Rotor / Shaft Break Affected Analysis No 6.3.5.1 Uncontrolled Rod Control Cluster Assembly Bank Withdrawal Affected Analysis and Evaluation No From a Subcritical Condition Section 6.0 - Accident Analysis (continued) 6.3.5.2 Uncontrolled Rod Control Cluster Assembly Bank Withdrawal Affected Analysis No at Power 6.3.5.3 Rod Control Cluster Assembly Misoperation Affected Evaluation No

DRAFT SUPPLEMENTAL INFORMATION TABLE 1 (continued)

SEABROOK STATION AFFECTED / UNAF-ECTED MATRIX Change To Current LAR System / Component I Affected I Method Of spu Design Or Licensing Section Evaluation / Analysis Unaffected' Reconciliation Basis Acceptance Criteria 6.3.5.4 Startup of an Inactive Reactor Coolant Pump Unaffected Evaluation No 6.3.5.5 Chemical and Volume Control System Malfunction that Results Affected Analysis No in a Decrease in Boron Concentration in the Reactor Coolant 6.3.5.6 Inadvertent Loading and Operation of a Fuel Assembly in an Unaffected Evaluation No Improper Location 6.3.5.7 Spectrum of Rod Control Cluster Assembly Ejection Accidents Affected Analysis No 6.3.6.1 Inadvertent Operation of Emergency Core Cooling System Affected Analysis No During Power Operation 6.3.6.2 Chemical and Volume Control System Malfunction that Affected Analysis No Increases Reactor Coolant Inventory 6.3.7.1 Inadvertent Opening of a Pressurizer Safety or Relief Valve Affected Analysis No 6.3.8 Anticipated Transient Without Scram Affected Analysis and Evaluation No 6.3.9 Station Blackout Unaffected Evaluation No 6.4.1.1 Long-Term LOCA Mass and Energy Releases Unaffected Analysis No 6.4.1.2 Short-Term LOCA Mass and Energy Releases Unaffected Analysis and Evaluation No3 6.4.2 Sub-Compartment Analysis Unaffected Evaluation No3 6.4.3 Long Term Containment Response Unaffected Analysis No3 6.4.4 Main Steam Line Break Mass and Energy Releases Inside Unaffected Analysis No3 Containment Section 6.0- Accident Analysis (continued) 6.4.5 Steamline Break Containment Response Unaffected Analysis No3 6.5 Streamline Break Outside Containment Affected Analysis l No 6.6 Radiological Consequences Affected Analysis Note 4

DRAFT SUPPLEMENTAL INFORMATION TABLE 1 (continued)

SEABROOK STATION AFll1*;CTED / UNAFFECTED MATRIX LAR System / Component I T

Affected I IChange Method Of SPU To Current Design Or Licensing Section Evaluation / Analysis Unaffected1 Reconciliation Basis Acceptance Criteria Section 7.0 - Nuclear Fuel 7.1 Thermal-Hydraulic Design Affected Analysis No 7.2 Core Design Affected Analysis No5 7.3 Fuel Rod Design and Performance Affected Analysis No Section 8.0 - Balance of Plant 6 8.2 Heat Balances Affected Analysis No7 8.3 Turbine Generator and Turbine Auxiliary Systems Affected Analysis and Evaluation Nos 8.4.1 Main Steam Affected Analysis and Evaluation No 8.4.2 Extraction Steam Affected Analysis and Evaluation No 8.4.3 Condensate and Feedwater Affected Analysis and Evaluation No 8.4.4 Emergency Feedwater Unaffected Analysis and Evaluation No 8.4.5 Steam Generator Blowdown Unaffected Evaluation No 8.4.6 Main Condenser Evacuation System Affected Analysis and Evaluation No 8.4.7 Main Condenser and Circulating Water Affected Analysis and Evaluation No 8.4.8 Heater Drains Affected Analysis and Evaluation No 8.4.9 Spent Fuel Pool Cooling Affected Analysis and Evaluation No9 8.4.10 Containment Building Spray Unaffected Analysis and Evaluation No3 Section 8.0 - Balance of Plant6 (continued) 8.4.11 Ultimate Heat Sink Unaffected Evaluation No3 8.4.12 Service Water Unaffected Evaluation No'0 8.4.13.1 Primary Component Cooling Water Unaffected Analysis and Evaluation Nole 8.4.13.2 Secondary Component Cooling Water Unaffected Evaluation No

DRAINT SUPPLEMENTAL INFORMATION TABLE 1 (continued)

SEABROOK STATION AFFECTED / UNAFFECTED MATRIX Change To Currcnt LAR System / Component / Affected I Method Of SPU Design Or Licensing Section Evaluation / Analysis Unaffected' Reconciliation Basis Acceptance Criteria 8.4.14 Heating, Ventilation, and Air Conditioning Affected Analysis and Evaluation No 8.4.15.1 Rad Waste Systems Unaffected Evaluation No 8.4.15.2.1 Normal Operation Annual Rad Waste Effluent Releases Affected Analysis and Evaluation No 8.4.15.2.2 Post Accident Access to Vital Areas Affected Analysis and Evaluation No 8.4.15.2.3 Normal Operation Dose Rates and Shielding Affected Analysis and Evaluation No 8.4.15.2.4 Post Accident Environmental Levels Affected Analysis and Evaluation No 8.4.15.2.5 Radiation Monitor Setpoints Unaffected Evaluation No" 8.4.16.1 AC Distribution System Affected Analysis and Evaluation No 8.4.16.2 Powver Block Electrical Equipment Affected Analysis and Evaluation No 8.4.16.3 DC System Unaffected Evaluation No 8.4.16.4 Emergency Diesel Generator Fuel Oil and Lube Oil Systems Unaffected Evaluation No 8.4.16.5 Emergency Diesel Generators and Auxiliaries Unaffected Evaluation No 8.4.16.6 Switchyard Unaffected Analysis and Evaluation No 8.4.16.7 Grid Stability Affected Analysis12 No 8.4.17 BOP Instrumentation Affected Analysis and Evaluation No13 8.5.1 BOP Piping and Supports Affected Analysis and Evaluation No Section 8.0 -Balance of Plant 6 (continued) 8.5.2 NSSS Piping and Supports Affected Analysis and Evaluation No 8.6.1 Containment Structure Unaffected Evaluation No3 8.6.2 Containment Sub-Compartments Unaffected Evaluation No3 8.6.3 High Energy Line Break Outside Containment Unaffected Analysis and Evaluation No 8.6.4 Pipe Support Reactions Unaffected Analysis and Evaluation No

DRAFT SUPPLEMENTAL INFORMATION TABLE 1 (continued)

SEABROOK STATION AFFECTED / UNAli ECTED MATRIX Change To Current LAR System / Component/ Affected I Method Of SPU Design Or Licensing Section Evaluation / Analysis Unaffected' Reconciliation Basis Acceptance

_ _Criteria Section 9.0 - Programs 9.1.1 Fire Protection Program Unaffected Evaluation No 9.1.2 Valve Programs Unaffected Evaluation No 9.1.3 Flow Accelerated Corrosion Program Affected Analysis and Evaluation No 9.2 Equipment Qualification Program Affected Evaluation No Section 10.0 - Miscellaneous Topics 10.1 Mid-Loop Operation Affected Evaluation No 10.2 Natural Circulation Cooldown Affected Analysis No 10.3 Internal Flooding Unaffected Evaluation No 10.4 High Energy Line Break / Jet Impingement Unaffected Evaluation No 10.5 Probabilistic Safety Assessment Unaffected Evaluation No Section 11.0 - Impact on Operations 11.0 Impact on Operations l Affected Analysis and Evaluation No Section 13.0-Environmental Evaluation 13.0 Environmental Evaluation Unaffected I Analysis and Evaluation No

DRAFT SUPPLEMENTAL INFORMATION TABLE I (continued)

SEABROOK STATION AFFECTED / UNAFFECTED MATRIX Chiange To Current LAR System / Component/ Affected I Method Of sPu Design Or Licensing Section Evaluation / Analysis Unaflected' Reconciliation Basis Acceptance Criteria NOTES:

1. According to the NRC Guidance for Margin Uncertainty Recapture Power Uprtes in RIS 2002-03:

Unaffected - Unaffected systems, components, or safety analyses are those having current design and licensing bases analyses and calculations that bound the potential effects of the SPU.

Affected - Affected systems, components, or safety analyses are those having current design and licensing bases analyses and calculations that do not bound the potential effects of the SPU.

2. Materials requirements and evaluations continue to be applicable.
3. The SPU mass and energy releases for LOCA and Main Steam Line Break inside Containment are less than those in the current Seabrook Station analyses of record. As a result, the current licensing basis Containment peak pressure and peak temperature envelopes remain bounding for the SPU.
4. The accident radiological consequences at the analyzed SPU core power level of 3659 MWt were submitted to the NRC in FPL Energy Seabrook letter NYN-0306 1 in License Amcndmcnt Request 03-02 to adopt the Alternate Source Term methodology for Seabrook Station.
5. Core designs are checked for each reload cycle to ensure that design bases conditions are bounded.
6. The safety related functions (e.g., containment isolation, temperature control) were considered for the SPU and remain unchanged. The original licensing basis acceptance criteria for the remainder of BOP system and component functions were not detailed. The criteria required that the systems function to produce power and provide reliable operation with minimal transients or trips. For the SPU, these systems were compared to industry codes, standards, and criteria to determine acceptability.
7. There are no acceptance criteria for the heat balance per se. The heat balance results are the inputs used for BOP systems and components evaluations and analyses.
8. Confirmation that the existing Turbine Missile Analysis remains valid.

DRAFT SUPPLEMENTAL INFORMATION TABLE 1 (continued)

SEABROOK STATION AFFECTED / UNAFF; ECTED MATRIX Clhange To Current LAR System / Component/ Affected I Method Of SPU Design Or Licensing Section Evaluation / Analysis Unaffected' Reconciliation Basis Acceptance Criteria NOTES: (continued)

9. Although the temperature acceptance criterion of 140 0F (2000 F, and no boiling in the spent fuel pool) are not changed, the time for the spent fuel pool capability to match decay heat at SPU conditions has changed (e.g., 118 hours0.00137 days <br />0.0328 hours <br />1.951058e-4 weeks <br />4.4899e-5 months <br /> to 134 hours0.00155 days <br />0.0372 hours <br />2.215608e-4 weeks <br />5.0987e-5 months <br />).
10. The total heat loads for normal operation and normal cooldown at SPU conditions are bounded by current design values. Although the SPU heat loads for extended cooldown and LOCA are greater than original values, the heat loads are still within the design capability of the heat removal systems without a change in flow rates, equipment, or system operation.
11. The radiation monitor setpoint bases remain valid for the SPU. The actual setpoints of the monitors may change slightly to correspond to an increase in radiation level (background or process) as a result of the SPU.
12. The Grid Stability Analysis was performed by ISO New England.
13. Evaluation was based on revised heat balance parameters and applicable system analysis compared to instrument ranges. Changes required include banding (external coloring) for the feedwater and main steam flow indicators in the Control Room, and two non-safety related setpoint changes.

U. S. Nuclear Regulatory Commission NYN-04OXX / Page 13 Bullet 2:

For those BOP areas (Matrix 5 of RS-001) that are potentially impacted:

+ All instances where existing design and licensing basis criteria and commitments are not satisfied under SPU, where criteria are not used consistently, or where SPU conditions are not bounded by previous analyses, should be clearly identified, discussed in detail (including impact on plant operation), and fully justified. This would include (for example) any changes in analytical methodologies or assumptions, taking credit for additional operator actions or crediting operator response times that are less conservative than previously assumed, and failure to satisfy design specifications. A summary listing of any exceptions should be included in the submittal to facilitate NRC review.

+ All instances where SPU conditions will result in challenges to BOP equipment or marginal performance that could have a safety impact should be highlighted for NRC review and consideration.

+ Measures for assuring compliance with vendor recommendations and standard industry practice, including any restrictions that will be placed on plant operation, should be discussed. Operation that could impact safety that is contrary to existing criteria, vendor recommendations, and/or applicable industry standards should be fully justified.

+ The considerations referred to in the Regulatory Evaluation Sections of RS-001, Section 3.3, Insert 5, should be addressed.

FPL Energy Seabrook Response:

See FPL Energy Seabrook response to Bullet 1. Additionally, the following should be noted:

  • Only NRC approved analytical methodologies were used to demonstrate that the SPU meets design and licensing criteria.
  • All assumptions regarding operator actions and response times are consistent with the current licensing basis (pre-SPU).
  • There are no instances where BOP systems and equipment that have an impact on safety will fail to satisfy design specifications.
  • There are no instances where BOP systems and equipment that have an impact on safety will be challenged or have marginal performance.
  • There are no instances where BOP systems and equipment that have an impact on safety will not comply with existing criteria, vendor recommendations, and/or applicable industry standards.
  • FPL Energy Seabrook utilized RS-001, including the Section 3.3 inserts, as input for preparation of SPU system and component evaluations and the LAR.

U. S. Nuclear Regulatory Commission NYN-04OXX / Page 14 Attachment I Bullet 3:

Acceptance should be based on satisfying all existing licensing-basis criteria, including applicable commitments that have been made. A summary of the basis for acceptance, including a brief discussion of the bounding considerations and acceptance criteria that are impacted by SPU; analyses that have been completed; and a comparison of the existing capability vs. the capability following SPU implementation vs. the licensing-basis acceptance criteria should be included for each area of review.

FPL Energv Seabrook Response:

See FPL Energy Seabrook response to Bullet 1. Additionally, based on the analyses and evaluations performed for the SPU, the Seabrook Station licensing bases, as revised by the LAR accident analyses (Attachment 1, Section 6.0) and Technical Specification changes (Attachment 2), and applicable commitments are satisfied.

U. S. Nuclear Regulatory Commission NYN-04OXX / Page 15 Bullet 4:

A discussion of the startup testing program, including a description of how analytical conclusions will be confirmed, should be provided (see RS-001 for guidance). In particular, where existing design criteria will not be satisfied or marginal performance is expected under SPU conditions, plant performance should be confirmed during plant startup and initial full power operation against suitable acceptance criteria.

FPL Energy Seabrook Response:

Power Ascension Testing The planned Seabrook Station SPU testing is described in LAR Attachment 1, Section 12.0 (page 12-1). The test plan has been developed and is summarized below in Table 2 - "Seabrook Station SPU Power Ascension Test Plan Summary." Although it is not required for an SPU, the test plan was developed consistent with the guidance of RS-001, "Review Standard for Extended Power Uprates," and as applicable, NUREG-0800, Draft Section 14.2.1, "Generic Guidelines for Extended Power Uprate Testing Programs."

The purpose of this plan is to demonstrate that changes made to the plant hardware and instrumentation and control systems have been properly designed and implemented, and to demonstrate that the plant can be operated safely at the SPU power level. Implicit in the mission of this comprehensive post-modification and power ascension test plan is the demonstration that the engineering calculations are correct and that the SPU operation is bounded by the analysis that was performed. The SPU test plan has been developed to confirm satisfactory plant performance for low power physics testing and full power operations at the SPU power level, and to demonstrate that all design criteria are satisfied.

The test plan was developed considering three aspects: 1) power ascension testing, including low power physics testing, 2) vibration monitoring, and 3) post-modification testing for the plant changes.

First, following completion of post refueling low power physics testing, power ascension testing necessary to ensure that the plant can be safely operated at the SPU power level will be conducted. The methodology used for this aspect was to review each test listed in UFSAR Table 14.2.5, Initial Test Program, for applicability to the plant restart after the modifications required by the SPU have been implemented. The Initial Test Program, as described in Chapter 14 of the Seabrook} Station UFSAR was planned using a methodology similar to NUREG-0800, Section 14.2, "Initial Test Program - Final Safety Analysis Report." The modifications required for the SPU and modifications to improve margins, plant performance and efficiency are listed in the SPU LAR 04-03, Attachment 1, Section 10.6 (page 10-7). Additionally, modifications that are being performed that are not required for the SPU and not identified in the LAR, were considered in the development of Table 2.

Second, vibration monitoring will be performed on systems and components reasonably affected by the SPU and the attendant increases in steam and feed flow (See below).

U. S. Nuclear Regulatory Commission NYN-04OXX / Page 16 Third, post-modification testing will validate the engineering analysis and implementation of the changes. Post-modification tests for each modification will be carried out in accordance with plant design process procedures.

A dedicated SPU restart procedure will be written to temporarily supercede the normal restart procedure. The SPU restart procedure will be written to: 1) control the sequence and coordination of existing plant startup procedures with the new procedures written to validate the changes due to the SPU, 2) ensure the engineering analysis and subsequent implementation of modifications, including setpoint changes and calibrations, are correct, and 3) allow safe ascension to the SPU power level. This temporary procedure will reference dedicated SPU test procedures, including the gathering of plant thermal and electrical performance data. The SPU test procedures and results will be reviewed and approved by plant engineering, management, and the site safety review committee. In accordance with Seabrook Station Technical Specifications, Section 6.8.1.1, a startup report for the SPU will be generated and sent to the Nuclear Regulatory Commission within 90 days of completing the startup test program.

Table 2 below describes the testing and data collection for the SPU, related modifications, and areas of increased monitoring.

U. S. Nuclear Regulatory Commission NYN-04OXX / Page 17 Attachment 1 TABLE 2 SEABROOK STATION SPU POWER ASCENSION TEST PLAN

SUMMARY

SYSTEM IMODIFICATION DESCRIPTION TESTS CO__PONENT _ (See LAR Section 10.6)

Main Turbine Modify high pressure 1) Post-modification performance test turbine steam path 2) Overspeed test

3) Vibration baseline with post-modification monitoring
4) Turbine thermal performance Turbine - Generator Set Overall SPU changes 1) Torsional tests
2) Electric performance tests Moisture Separator Replace moisture 1) Post-modification performance test Reheaters separator reheater internals 2) Monitoring during power ascension for expected thermal parameters Heater Drain Piping Replace system valves as 1) Monitor for excess movement and vibration required 2) Monitor heater drain tank and feedwater heater levels Condensate Pumps Upgrade condensate pump 1) Full flow test in vendor's shop impellers 2) Monitor discharge pressure and flow
3) Monitor pump vibration Main Feedwater Pump Change speed controller 1) Monitor pump speed setpoint 2) Monitor discharge pressure and flow Note: Speed to remain 3) Monitor pump vibration the same and flow increases due to increased suction pressure BOP Systems piping and Heater drain pump flow components increase 1) Monitor pumps for vibration (Main Steam, Extraction Steam and feed flow Steam, Condensate and increases 2) Monitor piping for excess movement and Feedwater, Heater Drain) vibration.

Generator Step-up Increase generator step-up Monitor cooling performance including verification Transformer Coolers transformer cooler of temperature data.

capability Instrumentation and Setpoint changes Verify setpoint changes correctly implemented via the Control Systems Seabrook Station design control program.

U. S. Nuclear Regulatory Commission NYN-04OXX / Page 18 Attachment 1 TABLE 2 (continued)

SEABROOK STATION SPU POWVER ASCENSION TEST PLAN

SUMMARY

SYSTEM I MODIFICATION TESTS COMPONENT DESCRIPTION

. ___ (See LAR Section 10.6)

Power Ascension Testing Summary Major Prerequisites

  • Plant in Mode 2
  • Post refueling low power physics testing completed
  • Stearnflow normalization factors reviewed.
  • Feedwater temperature bias constants reviewed.
  • Quadrant Power Tilt Ratio (QPTR) normalization factors set to 1.0.
  • Software to support analysis of the upcoming fuel cycle has been successfully installed on the Reactor Analysis Workstation.
  • Calorimetric software is set to the appropriate mode
  • Turbine impulse pressure scaling has been reviewed.

Rod Control System NA 1) Drop time measurement

2) Position indication
3) Worth measurement (See Prerequisites)

Reactor, Reactor Coolant NA Vibration and loose parts monitor in service System piping and Steam Generator internals Ventilation Systems NA Ventilation system operability test (Reference Technical Requirements Manual (TRM))

Chemical and Volume NA Maintain primary and secondary chemistry within the Control System requirements of the Chemistry Control Program.

Plant Process Computer NA 1) Validate control and test software for the Main Plant Computer System.

2) Verify calorimetric calculation is correct.

Reactor Core NA Utilize plant procedures for post-refueling power physics testing and Seabrook uprate power ascension testing to verify applicable core design parameters.

U. S. Nuclear Regulatory Commission NYN-04OXX / Page 19 TABLE 2 (continued)

SEABROOK STATION SPU POWVER ASCENSION TEST PLAN

SUMMARY

SYSTEM I/ MODIFICATION TESTS COMPONENT DESCRIPTION (See LAR Section 10.6)

NSSS NA 1) Utilize the Seabrook uprate power ascension testing procedure to trend parameters, evaluate data, and rescale instrumentation (AT, Nuclear Instrumentation, turbine impulse pressure).

2) Ensure systems that determine reactor thermal power are properly calibrated.

Engineered Safety NA Utilize the plant technical specification surveillance Features Equipment program to verify operability of Engineered Safety Features Systems.

Plant Radiation Levels NA Utilize Seabrook Station Radiation Protection Manual to verify acceptable plant radiation levels.

Piping Vibration Vibration monitoring, where appropriate, has been addressed in the planning of post-SPU testing. In the development of the system engineering evaluations supporting the SPU, vibration affects were evaluated with consideration of the increase in flow. System health reports, periodically prepared and issued as part of an ongoing program, were reviewed for outstanding vibration issues.

For the Seabrook Station SPU, there is no mass or volumetric flow rate change in the Reactor Coolant System (primary side). Therefore, vibration issues on the primary side of the plant are not expected.

On the secondary side, most flow rates will increase in proportion to the increase in power. Flow rates and/or velocities in the main steam, extraction steam, heater drain, and condensate and feedwater systems were evaluated and found to be acceptable. System walkdowns will be performed during power ascension to the SPU power level to ensure vibrations for piping systems, and components remain acceptable. System walkdowns are performed under the standardized plant engineering guideline procedure. The procedure specifically calls for the monitoring of vibration. Equipment vibration will be monitored under the ongoing plant Condition Based Maintenance Program. Vibration issues, if any, for the pre-SPU plant (at shutdown) will be established via the system walkdown and Condition Based Maintenance Program.

The turbine-generator and moisture separator reheaters will also be monitored during power ascension.

U. S. Nuclear Regulatory Commission NYN-04OXX / Page 20 Specific BOP piping or components that are in the vibration monitoring scope include:

1. BOP systems
  • Moisture separator reheater and heater drain lines
2. Turbine-generator.
3. Components - feedwater, heater drain, and condensate pumps and motors Note: Main feedwater pump speed will remain at approximately the same speed as current operation. Increased feedwater flow results from increased feedwater pump suction pressure. The increased suction pressure is generated by an enhanced condensate pump impeller design.

U. S. Nuclear Regulatory Commission NYN-04OXX / Page 21 Observation #1:

Does methodology satisfy licensing basis criteria in all respects; are there any exceptions?

[Attachment 1, Section 1.2, Pages 1-4, 1-5)

FPL Energy Seabrook Response:

The methodology utilized for SPU analyses and evaluations satisfy the Seabrook Station licensing basis, as revised by the LAR accident analyses (Attachment 1, Section 6.0) and Technical Specification changes (Attachment 2), without exception.

U. S. Nuclear Regulatory Commission NYN-04OXX / Page 22 Attachment I Observation #2:

What "expectations" of RS-001 are not satisfied? [Attachment 1, Section 1.3, Page 1-8)

FPL Energv Seabrook Response:

As provided in the matrices in LAR Attachment 1, Tables 1.3-1 through 1.3-13 (page 1-9), and the evaluations and analysis in the referenced LAR sections, FPL Energy Seabrook considers that all expectations of RS-001 are satisfied.

U. S. Nuclear Regulatory Commission NYN-04OXX / Page 23 Observation #3:

With respect to Note 1, what about any impact due to plant modifications? Also, there should not be two different "Note 1', listings. [Attachment 1, Table 1.3-5, Page 1-12]

FPL Energy Seabrook Response:

There are no plant modifications associated with the SPU that will impact the conclusions in Note 1 of LAR Attachment 1, Table 1.3-5 (page 1-12). Although there are two different "Note 1" listings, the "Note 1" in LAR Attachment 1, Table 1.3-5 (page 1-12) applies to both "Internally Generated Missiles" table entries, and the "Note 1" in LAR Attachment 1, Table 1.3-5 (page 1-13) applies to the "Light Load Handling System" table entry.

U. S. Nuclear Regulatory Commission NYN-04OXX / Page 24 Observation #4:

The NSSS parameter acceptance criteria should include "within the bounds of the existing licensing basis." [Attachment 1, page 2-2, Section 2.4]

FPL Energy Seabrook Response:

The acceptance criteria for the SPU parameters is that they provide Seabrook Station with adequate flexibility and margin for plant operation within the bounds of the current licensing basis as revised by the Accident Analysis in LAR Attachment 1, Section 6.0 and the Technical Specification changes in LAR Attachment 2.

U. S. Nuclear Regulatory Commission NYN-04OXX / Page 25 Observation #5:

With respect to Note 1, is this consistent with the plant licensing basis? [Attachment 1, Table 4.1-1, Page 4-10]

FPL Energy Seabrook Response:

The BOP Curve identified in LAR Attachment 1, Table 4.1-1 (page 4-10) was used as the decay heat model for the current licensing basis for Seabrook Station, and the Residual Heat Removal cooldown analysis for the SPU used the same model. Thus, use of the.BOP Curve is consistent with the current licensing basis.

U. S. Nuclear Regulatory Commission NYN-04OXX / Page 26 Observation #6:

Why is criteria ok? What is steam generator pressure increase following load rejection? What was original licensing basis criteria? [Attachment 1, Section 4.2.3.3.2, Page 4-17]

FPL Energv Seabrook Resnonse:

The maximum design load rejection is the most limiting transient for operation of the Condensate and Feedwater Systems. Seabrook Station was originally designed and licensed for a maximum load rejection of 50 percent of full power without a reactor trip, crediting automatic reactor control including rod control, steam generator level control, pressurizer pressure and level control, and steam dump control. In order to meet this licensing basis, adequate feedwater flow must be provided to the steam generators to prevent a reactor trip on low steam generator water level. As a result, Westinghouse established an balance of plant interface criteria for the Condensate and Feedwater Systems which required that the systems be able to supply 103 percent of the rated feedwater flow, assuming a 75 psi increase above full load steam pressure and the feedwater control valves wide open. Accordingly, in order to meet the Seabrook Station licensing basis for the SPU, the Condensate and Feedwater Systems must be capable of supplying 103 percent of the rated feedwater flow (rated feedwater flow is the highest steam flow presented in LAR Attachment 1, Table 2.3-1 (page 2-3), or 16.52 million lb/hr) with a 75 psi increase above full load steam pressure and the feedwater control valves wide open. The system hydraulic evaluation summarized in LAR Attachment 1, Subsection 8.4.3 (page 8-18) was performed and demonstrated that the interface criteria, and thus the original licensing basis could still be achieved at the SPU conditions.

The 50 percent load rejection analysis performed for the SPU indicates that the peak steam generator shell side pressure is approximately 1075 psia which occurs about one minute into the event. Since this peak pressure is well below the set pressure for main steam system atmospheric dump valves and main steam safety valves, the valves will not lift during this transient.

U. S. Nuclear Regulatory Commission NYN-04OXX / Page 27 Observation #7:

Why not 102% power; do assumptions satisfy licensing basis; any exceptions? [Attachment 1, Section 4.2.3.4.1, Page 4-18)

FPL Energy Seabrook Response:

All SPU analyses were performed at the analyzed SPU core power level of 3659 MWt (3678 MWt NSSS power level) which is 102% of the requested licensed core power level (3587 MWt). All assumptions satisfy the licensing basis.

U. S. Nuclear Regulatory Commission NYN-04OXX / Page 28 Observation #8:

Why are "best estimate" values used? Is this consistent with licensing basis? [Attachment 1, Table 8.2-1, Page 8-5]

FPL Energv Seabrook Response:

The "best estimate" discussion / clarification in Note 1 for the heat balance parameter entries contained in LAR Attachment 1, Table 8.2-1 (page 8-5), was provided to differentiate these BOP parameters from the similar main steam flow values presented in the "Design Operating Parameters" presented in LAR Attachment 1, Table 2.3-1 (page 2-3). The information contained in LAR Attachment 1, Table 2.3-1 is used for various NSSS accident analyses and thus may be different.

The current and SPU parameters summarized in LAR Attachment 1, Table 8.2-1, were developed based on conservative design heat balance models which were "tuned" to correspond to the current plant performance (Refer to LAR Attachment 1, Section 8.2, page 8-3). The parameters provided in LAR Attachment 1, Table 8.2-1 were developed utilizing heat balances based on an analyzed SPU core power level of 3659MWt (3678 MWt NSSS power level) which is 102% of the requested licensed core power level of 3587 MWt. Margin was also provided in the hydraulics analysis of the condensate and feedwater pump capacity to account for potential pump wear. Thus, the parameters provided in this table are conservative and consistent with the licensing basis.

U. S. Nuclear Regulatory Commission NYN-040XX / Page 29 Observation #9:

No details about the turbine-generator evaluation, overspeed protection, auxiliaries are provided, just conclusion. [Attachment 1, Section 8.3 Pages 8-11/12)

FPL Energy Seabrook Response:

Turbine Generator The evaluation of the turbine-generator and associated auxiliary equipment is summarized in LAR Attachment 1, Subsection 8.3 (page 8-11). The following supplemental information provides additional details of the evaluation.

The evaluation, performed by General Electric Energy Services (GE), assessed the impact of increases in throttle flow on the Seabrook Station turbine-generator at the corresponding rated throttle pressure. These evaluations were based on the heat balances for SPU flow conditions and output increases at the analyzed core power level of 3659 MWt (3678 MWt NSSS power level).

The objective of the evaluation was to maintain adequate design margins, to provide long life and trouble-free operation, and to meet the SPU objectives for performance and capacity. To achieve these objectives, these evaluations examined whether any modification and replacement requirements would be necessary to implement operation of the unit at SPU steam conditions.

GE engineering practice is to maintain adequate design margins when evaluating an existing turbine-generator unit for operation at an uprated condition to ensure high standards of reliability and output at the uprated operating conditions. Therefore, the bases of the SPU evaluations were to evaluate the actual mechanical margins that exist in the turbine-generator at the SPU design conditions relative to the current design standards and to determine if there were technical issues with operating the unit at the SPU conditions.

Thermodynamic, mechanical, and operational scenarios were considered and evaluated at the SPU conditions that produce the maximum stress levels. Components were evaluated on the basis of these SPU conditions. This established the foundation for the SPU evaluations and where applicable, recommendations to replace or modify turbine-generator components. This design philosophy was intended to result in reliability and integrity equivalent to what would be expected for a new unit designed for the same steam conditions and service. GE will design the new components provided for the high pressure turbine modification to current GE engineering design standards.

New turbine steam specification data were developed for the SPU conditions using the thermodynamic cycle specifications for the SPU valves wide open conditions which are in excess of the SPU analyzed power level mentioned above. Analyses were performed in the following areas using the new turbine steam data:

  • Steam specifications for each turbine stage, including temperature and pressure absolute levels, pressure differentials, and expected stage kilowatt outputs;
  • Shells, casings, and bolting at the increased temperature and pressure levels;

U. S. Nuclear Regulatory Commission NYN-04OXX / Page 30 Attachment 1

  • Stationary steam path components for increased temperature and pressure levels, and pressure differentials;
  • Turbine bucket stresses for the expected increased stage outputs;
  • Rotors for increased torsional loads;
  • Couplings for increased torsional loads and output transmission (including bolting);
  • Rotor dynamics and stability;
  • Increased thrust loads and potential thrust imbalances;
  • Increased journal bearing loads and temperatures;
  • Review of turbine piping and relief valves;
  • Stop, control, and combined intermediate valves for increased flows and pressures;
  • The valves wide open mechanical review of the turbine evaluated steady-state, impact, and
  • Vibratory stresses due to abnormal operations that might affect the turbine operation.

Typical steady-state stresses are wheel and rotor torsional loadings, bucket steam-bending stresses, and pressure differential loadings across shells, casings and diaphragms.

Shells and Casings:

The shells, casings and horizontal bolting of the Seabrook Station turbine were evaluated for SPU operation at the elevated pressure levels throughout the turbine consistent with the throttle pressure of 979.3 psia at valves wide open. The review included analysis of shell stresses; bending, shear, and crush stresses for the diaphragm ledges; ledge thickness; and horizontal joint bolting. The in-service shells, casings and bolting all have adequate design margin for continued reliable service under the SPU conditions and, therefore, no modifications to these components are necessary.

First Stage Nozzle Plates and Diaphragms:

The first stage nozzles and subsequent high pressure turbine diaphragms were not evaluated, as they will be replaced as part of the high pressure turbine modifications. The low pressure turbine diaphragms were evaluated for the SPU steam conditions and valves wide open operation. The results demonstrated that the low pressure turbine diaphragms have adequate structural design margins for operation at the SPU steam conditions. The small change in the steam moisture content associated with the power SPU has negligible effect on the erosion/corrosion of the steam path components.

The maintenance history on the current turbine shows that the diaphragms have required only normal maintenance.

U. S. Nuclear Regulatory Commission NYN-04OXX / Page 31 Attachment 1 Turbine Buckets:

The Seabrook Station turbine consists of seven double-flow high pressure stages in a turbine shell casting and three sets of seven double-flow low pressure stages in three separate exhaust hoods. The method of evaluating the dynamic stress of buckets, other than the first stage or standard-design latter low pressure stage buckets, is through the use of a calculated parameter termed the load factor. The first high pressure stage buckets are exposed to special loadings, which are governed by other design criteria. These other design factors affect the performance of the bucket row during startups and off-peak load operation.

The load factor was developed as a design parameter and was based on an evaluation of the steam bending moments and stress, and on a comparison of this value with operating experience.

The first stage buckets and subsequent high pressure buckets were not evaluated, as they will be replaced as part of the high pressure turbine modifications. With the steam flow increase for the SPU, the load bucket factors for each stage increase for all seven low pressure turbine bucket stages. For the SPU valves wide open steam conditions, the buckets will remain within the normal design limits and therefore, are acceptable for the SPU. The low pressure turbine stage temperature increases were calculated to be small and would thus have a negligible effect on the bucket and rotor material strength. All other bucket stresses, such as the centrifugal stress, are within the allowables for the original and SPU steam conditions.

Turbine Rotors:

A mechanical review of the turbine rotors was conducted to evaluate steady-state, vibratory, and upset stress conditions that are affected by the SPU steam conditions and loadings. Typical steady-state stresses are wheel and rotor torsional loadings and steam bending stresses. Rotor dynamics and stability, as well as rotor critical speeds and bucket group vibration, are examples of vibratory reviews that were conducted to ensure that the latest GE technology is applied in evaluating the turbine design for SPU steam conditions and flow capacity. In addition, the rotors were evaluated for transient and impulse step conditions such as synchronization out-of-phase and short circuiting of a line to ground fault. These factors can impose impact loadings on the shaft and couplings that are significantly larger than those experienced when operating at steady state. These situations were reviewed to determine if the currently installed rotors could be reliably operated at the SPU conditions based on the latest GE design criteria. The review analysis indicates that steady-state and upset conditions affecting the current rotor train are within normal design limits for the SPU conditions. Rotor multi-span critical speeds and rotor stability margins will also remain within design guidelines. There are no significant changes to the rotor assembly inertias and natural frequencies since these characteristics depend on the dimensional configuration of the rotating elements and steam temperatures. For this SPU, the Seabrook Station #2 high pressure rotor will be used, which has the same design as Seabrook Station #1 and all low pressure rotors will be re-used. The SPU only represents a small incremental change in the steam conditions.

During the development of the Seabrook Station turbine at the original design stage, several stresses and other requirements were independently evaluated. GE has followed a practice of using screening liifits in order to minimize the number of mathematical iterations performed during this phase. Another limit, defined as experience limit, was also established and based on

U. S. Nuclear Regulatory Commission NYN-04OXX / Page 32 the experimental and operating experience of GE turbines. This limit was used as the maximum allowable stress that the turbine rotors could be operated without reliability concerns. The low pressure rotor torsional stresses increase by approximately 4% at the SPU valves wide open steam conditions as a result of the increased transmitted torque. At these design valves wide open steam conditions, the calculated rotor torsional steady-state stresses exceed normal screening linits for design at the number 6, 7 and 8 journal bearing locations. However, these stresses are within the experience limit, and therefore will be acceptable for the SPU conditions.

The short circuit and synchronization out-of-phase stress values are below the screening limit.

With re-use of the high pressure rotor design and re-use of the complete low pressure rotors for this SPU, the SPU condition has no effect on the turbine-generator rotor torsional frequency characteristics. No additional testing or analysis will be required with respect to the rotor torsional dynamics.

Steam Piping:

The main steam inlet piping and the crossaround piping were evaluated for the SPU steam conditions and valves wide open operation. The results demonstrated that this piping has adequate structural design margins for operation at the SPU steam conditions. The small change in the steam moisture content associated with the SPU has negligible effect on the erosion/corrosion of these pipe components. The steam flow velocities are acceptable at the SPU flow volumes. Therefore, no changes or modifications are required for the main steam piping and crossaround piping.

Valves:

The existing angle body main stop-control valve casings were designed for 1250 psig operating pressure, and therefore are adequate for the SPU steam conditions. The existing control valve operating cylinders are also adequate for the higher throttle pressure.

The pressure drop from the combined intercept valve inlet to the low pressure turbine bowl is approximately 3.4 %, and is expected to remain the same for the SPU because the increased low pressure flow is achieved entirely by a corresponding increase in crossaround pressure. The combined intercept valves are satisfactory for the SPU.

The steam flow velocities are acceptable at the SPU flow volumes. The control valves currently operate at 2 admissions and will continue to do so after SPU implementation. Therefore, no changes or modifications are required for the stop valves, control valves or combined intercept valves.

Thrust Review:

The present thrust bearing in the unit is located in the turbine standard between the double flow high pressure section and the low pressure turbine A hood. It is a Straddle Independently Mounted Bearing with an active area of 300 square inches. The turbines consist of opposed double-flow sections, and because of this symmetry, the unit is ideally balanced with the

U. S. Nuclear Regulatory Commission NYN-04OXX / Page 33 Attachment 1 exception of the end-packing regions which have low pressure associated with small diameter step changes which result in low thrust. The current thrust bearing has adequate design margin and the SPU would not significantly change the total thrust of the unit and therefore no modification are needed for the thrust bearing.

The existing journal bearings are elliptical liner bearings. Since the bearing loadings will not be affected by the SPU steam conditions, the load carrying capacity of the bearings is adequate for the SPU conditions.

Moisture Separator Reheater Vessels:

The Seabrook Station moisture separator reheater system includes six cross-around relief valves between the moisture separator reheater vessels and the low pressure turbine inlets. While the moisture separator reheater vessel normal operating pressure will increase to around 190 psia with the SPU, this pressure will still be less than the 270 psig maximum pressure capability of the moisture separator reheater vessels. Crossaround relief valves protect the crossaround components from excessive pressure in case the intercept valves malfunction.

Allowable relief valve settings have been identified for reference purpose in order to assure that pressure limitations of the moisture separator reheater vessels are not exceeded. These allowable limits are met for the SPU steam conditions.

Turbine Lubricating Oil System:

Since no bearing modifications (journal bearings and thrust bearing) are required, the present lube oil system will be adequate and no modifications would be required for the SPU.

Rotor Train Overspeed Potential:

The increase in steam flow volumes will increase the potential for rotor overspeed during loss of load transients. An evaluation of overspeed potential has been performed by GE as part of the high pressure turbine modification redesign. The evaluation demonstrated that current overspeed trip settings will not have to be changed for the SPU conditions (see further discussion below).

Steam Seal System:

The basic design of the steam seal system will remain unchanged. The levels of change in the flows through the steam seal system are small and will not require any modifications to the retained components.

Unit History Review:

The GE Product Service records for this turbine were reviewed. The records reviewed included GE initiated field modifications, alignment records, and technical service communications between GE and Seabrook Station regarding turbine operation. The engineering records for this

U. S. Nuclear Regulatory Commission NYN-04OXX / Page 34 turbine were reviewed including original manufacturing deviation drawing records, field modification drawing records, and drawing records of spare parts provided. Nothing was found in any of the records that would affect the ability of this turbine to accommodate the SPU.

The generator review included the following components:

  • Rotor shaft
  • Field winding
  • Current transformers
  • ALTERREX excitation system Turbine Missile Probability and Overspeed Setting In addition to the mechanical review of the turbine rotors described above, wheel missile probabilities for the low pressure turbine rotors currently installed, in combination with the modified high pressure turbine, were recalculated. The results of this analysis demonstrated that the total probability of missile generation by the turbine, when operating at SPU conditions, will be less than the probability (PI) stated in Section 3.5.1.3 of the Seabrook Station UFSAR, and therefore would be acceptable.

As mentioned above, the analysis and evaluation of the turbine performed by GE included a verification that the current overspeed trip setpoints remain acceptable.

U. S. Nuclear Regulatory Commission NYN-04OXX / Page 35 Observation #10:

EFW: What elements of current licensing basis are affected; how does current capability compare with SPU capability (quantitative discussion); what is the licensing basis acceptance criteria; why acceptable?

FPL Energy Seabrook Response:

The current licensing basis of the Emergency Feedwater System is unaffected by the proposed SPU. As described in LAR Attachment 1, Subsections 4.2.3.4 and 8.4.4 (pages 4-17 and 8-22, respectively), the Emergency Feedwater System design requirements do not change for the proposed SPU and, hence, the system and components will continue to provide the required core decay heat removal for design basis events following the implementation of the proposed SPU.

The Emergency Feedwater System will also continue to meet the requirements of General Design Criteria 4, 19, 34, and 44.

The flow requirements of the Seabrook Station Emergency Feedwater System are dictated by the accident analyses, including the Condition II limiting requirement of a total of 650 gpm from one Emergency Feedwater Pump. These limiting transients and accident analyses were performed to confirm that the Emergency Feedwater System capability is acceptable at the SPU conditions, and are described in LAR Attachment 1, Subsections 6.3.2, 6.3.3.2, and 8.4.4 (pages 6-72, 6-106, and 8-22, respectively). The analysis demonstrates that for the limiting transient and accident analyses, the Emergency Feedwater System is capable of removing the stored energy, residual decay heat, and reactor coolant pump heat, maintaining required steam generator level, and preventing the pressurizer from becoming water-solid.

The maximum required condensate storage tank capacity is based on the limiting event of loss-of-offsite power and is described in LAR Attachment 1, Subsection 4.2.3.4.1 (page 4-18) in further detail. The current licensing basis requires that in the event of loss-of-offsite power, sufficient condensate storage tank usable inventory must be available to bring the unit from full power to hot standby conditions, maintain the plant at hot standby for four hours, and then cooldown the reactor coolant system to the residual heat removal system cut-in temperature (350'F) in five hours. Since the required condensate storage tank storage inventory is a function of plant rated power and other NSSS design parameters, a new analysis was performed to determine required inventory for the range of NSSS parameters for the proposed SPU. The analysis concluded that a minimum usable inventory of 190,000 gallons meets the licensing basis for the SPU. Therefore, no change is required to the condensate storage tank Technical Specification limit of 212,000 gallons.

U. S. Nuclear Regulatory Commission NYN-040XX I Page 36 Additional Information Requested During the Telephone Conversation on April 27. 2004:

During the telephone conversation with the NRC on April 27, 2004, several questions were raised regarding the evaluation of flow accelerated corrosion associated with balance of plant systems. Provided below is a clarification of the flow accelerated evaluation presented in LAR .

Flow Accelerated Corrosion (FAC) Program The intent of LAR Attachment 1, Subsection 9.1.3, "Flow Accelerated Corrosion Program," (page 9-2) was to address the impact of the SPU on all BOP systems currently in the Seabrook Station Flow Accelerated Corrosion Program, rather than address them individually in each BOP system section.

As summarized in LAR Attachment 1, Subsection 9.1.3, the primary objective of the Flow Accelerated Corrosion Program is to maintain the long-term process of flow accelerated corrosion detection and monitoring in piping systems, so that pipe wall thinning can be mitigated or reduced to prevent pipe failures. The major variables that affect the flow accelerated corrosion process have been identified as piping geometry, component internal geometry, piping material composition, fluid temperature, flow velocities, fluid chemistry (including pH and oxygen content), and moisture content. No changes to water chemistry are planned as a result of the SPU. Similarly, piping geometry, materials and associated components will not change. The remaining variables that could affect flow accelerated corrosion are fluid temperature, flow velocities, and moisture content.

The evaluations of the Main Steam, Extraction Steam, Condensate and Feedwater, and Heater and Moisture Separator Drains Systems are summarized in LAR Attachment 1, Subsections 8.4.1, 8.4.2, 8.4.3, and 8.4.8 (pages 8-13, 8-17, 8-18, and 8-28, respectively). These evaluations included an assessment of the changes in fluid temperature, flow velocities, and moisture content. In all cases, fluid temperature changes and moisture content changes as a result of the SPU were determined to be negligible. Velocity changes as a result of the SPU were also small

(-5-8%), and in all cases remained within accepted industry standards and economic line sizing criteria. Changes to piping flow velocities are summarized in Table 3 below. Note that the intent of LAR Attachment 1, Table 9.1.3-1 (page 9-4) was to demonstrate that flow accelerated corrosion wear rates remained within acceptable limits for the worst case piping system. These results would bound the effects of the SPU on other systems.

Piping systems that are susceptible to flow accelerated corrosion are currently modeled using the EPRI CHECWORKS computer program. As part of the implementation of the SPU, the current computer program will be revised to include the post-SPU operating parameters, including flow, temperature, pressure, and steam quality. The revised model will predict the new flow accelerated corrosion wear rates expected after the SPU, and these results will be utilized to select the inspection points required to establish new baseline data for significant wear areas.

During the refueling outage prior to the SPU implementation, the number of inspection points will be increased to include both those normally scheduled, and also the added points selected to obtain new baseline data. Following the SPU, Flow Accelerated Corrosion Program activities will be continued to monitor wear, and to take required corrective action during future plant operation.

U. S. Nuclear Regulatory Commission NYN-04OXX / Page 37 Attachment 1 TABLE 3 SEABROOK STATION BALANCE OF PLANT SYSTEM FLOW VELOCITIES LAR Subsection 8.4.1 - Main Steam System JCURRENT SPU Main Steam Header - Flow Velocity (fps) 118 124 LAR Subsection 8.4.2 - Extraction Steam System Extraction Steam to Extraction Steam to Extraction Steam to 26 Feedwater Heaters 25 Feedwater Heaters 24 Feedwater Heaters CURRENT SPU CURRENT l_SPU CURRENT SPU Flwelcty_119 150 148 183.1 101.8 109.8 Flow Velocity (fps) Extraction Steam to Extraction Steam to Extraction Steam to 23 Feedwater Heaters 22 Feedwater Heaters 21 Feedwater Heaters CURRENT SPU CURRENT l SPU CURRENT SPU 173 ( 178 204 206 180 179 LAR Subsection 8.4.3 - Condensate And Feedwater Systems CURRENT SPU Flow Velocities (fps) - '/' separates different piping sizes Hotwell to Condensate Pump Header 2.7 2.8 Condensate Pump Header (Main Header / Pump Inlet) 3.9 /5.1 4.1/5.4 Condensate Pump Discharge to Steam Packing Ejector (Pump Outlet / Packing Ejector Inlet) 8.5 /7.3 9.0/7.8 Steam Packing Exhauster to #21 Feedwater Heaters (Packing Ejector Outlet / Heater Inlet) 7.3 / 8.2 7.8/8.7 Number 21 to 22 Feedwater Heaters. 8.4 8.9 Number 22 to 23 Feedwater Heaters (#22 Outlet / Common / #23 Inlet) 8.5 /7.6/ 8.5 9.1 / 8.1/ 9.1 Number 23 to 24 Feedwater Heaters 8.8 8.9 Number 24 to 25 Feedwater Heaters (#24 Outlet / Common / #25 Inlet) 9.0/ 8.0/ 9.3 9.6/ 8.5 / 9.9 Number 25 to Feedwater Pump Suction 9.6 10.2 Feedwater Pump Suction 19.8 21.6 Feedwater Pump Discharge to #26 Feedwater Heaters (Pump Discharge / #26 Inlet) 23 / 16.0 25 / 17.3

  1. 26 Feedwater Heaters to Steam Generators (#26 Outlet / Steam Generator Inlet) 16.9 / 19.1 18.5/20.8 LAR Subsection 8.4.8 - Heater Drains CURRENT SPU Flow Velocities (fps) - 'I' separates different piping sizes Moisture Separator Reheater to Heater Drain Tank 0.6 / 1.0 0.8 /1.3 Reheater Drain Tank to #26 Feedwater Heaters 4.2 4.0
  1. 26 Feedwater Heaters to #25 Feedwater Heaters. to #24 Feedwater Heaters to
  1. 25 Feedwater Heaters Heater Drain Tank #23 Feedwater Heaters CURRENT SPU CURRENT I SPU CURRENT SPU

. 4.4 /10.4 J 4.6/10.8 5.3 j 5.5 3.9 4.2 Flow Velocity (fps)#23 Feedwater Heaters to #22 Feedwater Heaters to #21 #21 Feedwater Heaters to

  1. 22 Feedwater Heaters Feedwater Heaters Condenser CURRENTl SPU CURRENT SPU CURRENT SPU 5.8 1 6.2 3.4 l 4.3 3.7 / 12.1 3.9 /12.8

U. S. Nuclear Regulatory Commission NYN-04OXX / Page 1 ATTACHMENT 2 SPECIFIC NRC INFORMATION REQUEST

U. S. Nuclear Regulatory Commission NYN-04OXX / Page 2 DRAFT REQUEST FOR ADDITIONAL INFORMATION RELATED TO POWER UPRATE LICENSE AMENDMENT REQUEST SEABROOK STATION DOCKET NO. 50-443 By letter dated March 17, 2004, FPL Energy Seabrook, LLC (Seabrook or the licensee) submitted an amendment request. The proposed amendment would increase the maximum authorized reactor core power level for Seabrook from 3411 megawatt thermal (MWt) to 3587 MWt. This represents a nominal increase of 5.16% rated thermal power.

The U.S. Nuclear Regulatory Commission (NRC) staff has reviewed the information the licensee provided that supports the proposed amendment and requests the following additional information to clarify the submittal:

Based on our review of the licensee's submittal dated March 17, 2004, regarding a request for NRC to approve a stretch power uprate (SPU) for Seabrook, it has been determined that the licensee's submittal needs to be supplemented and documented with the following additional information in order to complete our acceptance review:

  • The submittal should identify those BOP areas (Matrix 5 of RS-001) that are potentially impacted from a safety perspective (including consideration of licensing basis criteria and commitments that have been made) as a result of the proposed SPU, and those that are not impacted (provide explanation for the "no safety impact determination," such as the original design-basis analysis is bounding). This will help to focus NRC review effort and expedite the completion of the review.

+ The SPU evaluation of BOP systems (Matrix 5 of RS-001) should include consideration of all design and licensing basis criteria that apply, including any commitments that have been made. Any instances where the plant licensing basis or commitments are not being satisfied as a result of the SPU should be specifically identified and justified in accordance with 10 CFR 50.59 requirements and the licensee's commitment tracking and control program.

  • For those BOP areas (Matrix 5 of RS-O01) that are potentially impacted:

+ All instances where existing design and licensing basis criteria and commitments are not satisfied under SPU, where criteria are not used consistently, or where SPU conditions are not bounded by previous analyses, should be clearly identified, discussed in detail (including impact on plant operation), and fully justified. This would include (for example) any changes in analytical methodologies or assumptions, taking credit for additional operator actions or crediting operator response times that are less conservative than previously assumed, and failure to satisfy design specifications. A summary listing of any exceptions should be included in the submittal to facilitate NRC review.

ATTACHMENT

U. S. Nuclear Regulatory Commission NYN-04OXX / Page 3

+ AU instances where SPU conditions will result in challenges to SOP equipment or marginal performance that could have a safety impact should be highlighted for NRC review and consideration.

+ Measures for assuring compliance with vendor recommendations and standard industry practice, including any restrictions that will be placed on plant operation, should be discussed. Operation that could impact safety that is contrary to existing criteria, vendor recommendations, and/or applicable industry standards should be fully justified.

+ The considerations referred to in the Regulatory Evaluation Sections of RS-001, Section 3.3, Insert 5, should be addressed.

Acceptance should be based on satisfying all existing licensing-basis criteria, including applicable commitments that have been made. A summary of the basis for acceptance, including a brief discussion of the bounding considerations and acceptance criteria that are impacted by SPU; analyses that have been completed; and a comparison of the existing capability vs. the capability following SPU implementation vs. the licensing-basis acceptance criteria should be included for each area of review.

  • A discussion of the startup testing program, including a description of how analytical conclusions will be confirmed, should be provided (see RS-O01 for guidance). In particular, where existing design criteria will not be satisfied or marginal perfonnance is expected under SPU conditions, plant performance should be confirmed during plant startup and initial full power operation against suitable acceptance criteria.

Specific Observations:

1. Does methodology satisfy licensing basis criteria in all respects; are there any exceptions?

[Attachment 1, Section 1.2, Pages 1-4, 1-5)

2. What "expectations" of RS-001 are not satisfied? [Attachment 1, Section 1.3, Page 1-8)
3. With respect to Note 1, what about any impact due to plant modifications? Also, there should not be two different "Note 1', listings. [Attachment 1, Table 1.3-5, Page 1-12]
4. The NSSS parameter acceptance criteria should include "within the bounds of the existing licensing basis." [Attachment 1, page 2-2, Section 2.4]
5. With respect to Note 1, is this consistent with the plant licensing basis? [Attachment 1, Table 4.1-1, Page 4-10]
6. Why is criteria ok? What is steam generator pressure increase following load rejection? What was original licensing basis criteria? [Attachment 1, Section 4.2.3.3.2, Page 4-17]
7. Why not 102% power; do assumptions satisfy licensing basis; any exceptions? [Attachment 1, Section 4.2.3.4.1, Page 4-18)

ATTACHMENIT

U. S. Nuclear Regulatory Commission NYN-04OXX / Page 4

8. Why are "best estimate" values used? Is this consistent with licensing basis? [Attachment 1, Table 8.2-1, Page 8-5]
9. No details about the turbine-generator evaluation, overspeed protection, auxiliaries are provided, just conclusion. [Attachment 1, Section 8.3 Pages 8-11/12)
10. dFW: What elements of current licensing basis are affected; how does current capability compare with SPU capability (quantitative discussion); what is the licensing basis acceptance criteria; why acceptable?

ATTACHMENT

TALKING POINTS / QUESTIONS FOR POTENTIAL REQUESTS FOR ADDITIONAL INFORMATION MAY 20 2004 PUBLIC MEETING WITH FPL ENERGY LLC, REGARDING POWER UPRATE LICENSE AMENDMENT REQUEST FOR SEABROOK STATION UNIT NO. 1

Electrical & Instrumention & Controls Branch Instrumentation & Controls Section Paul Loeser Please confirm that the following are the only safety related instrumentation setpoint changes required for the power uprate (PU)

A. Technical Specification Table 2.1-1, Reactor Trip System Instrumentation Trip Setpoints, Functional Unit 13, Steam Generator Water Level Low-Low is revised as follows:

1) The Trip Setpoint is changed from >14.0% to >20.0% of narrow range instrument span.
2) The Allowable Value is changed from >12.6% to >19.5% of narrow range instrument span.
3) The Total Allowance (TA), Z, and Sensor Error (S) are changed from values to N.A.

B. Technical Specification Table 3.3-4, Engineered Safety Features Actuation System Instrumentation Trip Setpoints, Functional Unit 5b, Turbine Trip, Steam Generator Water Level High-High (P14) is revised as follows:

1) The Trip Setpoint is changed from >86.8% to >90.8% of narrow range instrument span.
2) The Allowable Value is changed from >87.7% to >91.3% of narrow range instrument span.
3) The Total Allowance (TA), Z, and Sensor Error (S) are changed from values to N.A.

C. Technical Specification Table 3.3-4, Engineered Safety Features Actuation System Instrumentation Trip Setpoints, Functional Unit 6a, Feedwater Isolation, Steam Generator Water Level Hi-Hi (P14) is revised as follows:

1) The Trip Setpoint is changed from >86.8% to >90.8% of narrow range instrument span.
2) The Allowable Value is changed from >87.7% to >91.3% of narrow range instrument span.
3) The Total Allowance (TA), Z, and Sensor Error (S) are changed from values to N.A.

D. Technical Specification Table 3.3-4, Engineered Safety Features Actuation System Instrumentation Trip Setpoints, Functional Unit 7c, Emergency Feedwater, Steam Generator Water Level Low-Low, Start Motor-Driven Pump and Start Turbine-Driven Pump is revised as follows:

1) The Trip Setpoint is changed from >14.0% to >20.0% of narrow range instrument span.
2) The Allowable Value is changed from >12.6% to >19.5% of narrow range instrument span.
3) The Total Allowance (TA), Z, and Sensor Error (S) are changed from values to N.A.
2. In each case where the setpoint is shown as a percentage of instrument span, identify the instrument by manufacturer, model and range, its span, and the actual value of the setpoint and allowable value in physical values.
3. Please provide the calculations and supporting setpoint methodology document for the setpoints shown above. The detail should be sufficient to allow the staff to understand the values used, assumptions made, and formulae used. If the staff has previously reviewed and approved the setpoint methodology, please provide a reference to the acceptance document.
4. Please explain why, in each of the cases shown above, Total Allowance (TA), Z, and Sensor Error (S) are changed from values to N.A.
5. Please demonstrate for each of the functions shown above how channel operability is determined.
6. Are there any other changes to the instrumentation and controls needed beyond the setpoint changes identified, i.e., changes in control systems, span changes, or instrument replacements needed because of the power uprate?
7. Are there any changes to the compliance to SRP chapter 7 because of the power uprate?

License Renewal and Environmental Impacts Branch Environmental Section Lee Licata for June Cal 1: Describe how the proposed PU will change the plant emergency and abnormal procedures.

2a. Provide a list of systems that require new operating and maintenance procedures at the new PU.

2b. Provide a short description of each of the new procedures's intended purpose.

3a. Describe any new operator actions needed as a result of the proposed PU.

3b. Describe changes to any current operator actions related to emergency or abnormal operating procedures that will occur as a result of the uprate.

4a. Describe any changes the proposed PU will have on the Safety Parameter Display System.

4b. How will the operators know of the changes?

5a. Describe any changes the proposed PU will have on the operator training program and the plant referenced control room simulator.

5b. State the controlling standard for the simulator.

5c. Provide an implementation schedule for the PU modifications to the simulator.

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