ML24142A407
| ML24142A407 | |
| Person / Time | |
|---|---|
| Site: | Hope Creek  |
| Issue date: | 05/20/2024 |
| From: | Denight R Public Service Enterprise Group |
| To: | Document Control Desk, Office of Nuclear Reactor Regulation |
| Shared Package | |
| ML24142A428 | List:
|
| References | |
| LR-N24-0029, LAR H24-02 | |
| Download: ML24142A407 (1) | |
Text
Robert DeNight Hope Creek Generating Station Site Vice President, PSEG Nuclear
PO Box 236 Hancocks Bridge, New Jersey 08038-0221 856-339-5303 Robert.denightjr@pseg.com
LR-N24 -0029 LAR H24-02
May 20, 2024
U. S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001
Hope Creek Generating Station Renewed Facility Operating License No. NPF-57 NRC Docket No. 50-354
Subject:
License Amendment Request (LAR) - Hope Creek Technical Specification Conversion to NUREG-1433, Revision 5
Reference:
- 1. NUREG-1433 , Standard Technical Specifications - General Electric BWR/4 Plants, Revision 5 (ADAMS Accession Nos. ML21272A357 (Volume 1) and ML21272A358 (Volume 2))
Update to TSTF-360," (76FR54510)
In accordance with 10 CFR 50.90, PSEG Nuclear LLC (PSEG) hereby requests an amendment to Renewed Facility Operating License No. NPF-57 for Hope Creek Generating Station (Hope Creek). This license amendment request (LAR) would revise Hope Creek s current Technical Specifications (CTS) to the Improved Technical Specifications (ITS) consistent with the Improved Standard Technical Specifications (ISTS) (Reference 1). In accordance with 10 CFR 50.91(b)(1), a copy of this request for amendment has been sent to the State of New Jersey.
The following seven enclosures are included in this LAR:
- Enclosure 1 describes the organization and content of the submittal, including each of the volumes in Enclosure 2.
- Enclosure 2 contains 17 volumes that describe and justify the proposed changes.
Included in Enclosure 2 are the Bases for the proposed ITS. T he Bases are not part of the ITS but are maintained consistent with the Hope Creek Updated Final Safety Analysis Report (UFSAR) in accordance the Technical Specification Bases Control Program.
LR-N24-0029 10 CFR 50.90 Page 2
- Enclosure 3 lists and describes the changes included in the ITS submittal that differ from both the CTS and ISTS as described in Reference 1.
- Enclosure 6 summarizes the UFSAR descriptions that support the review of the Battery Monitoring and Maintenance Program. This enclosure provides, in part, the information and verifications requested in the Notice of Availability for TSTF-500, Revision 2 (Reference 2).
- Enclosure 7 contains proposed changes to the license conditions in the Hope Creek Operating License needed to support implementation of the ITS Conversion.
Two attachments are included to support the review of this ITS Conversion LAR.
provides information regarding Hope Creek systems that differ appreciably from the ISTS BWR-4 plant system design. This information is provided to assist the NRC in review of this ITS Conversion LAR .
provides a summary of the Hope Creek instrument setpoint control program and a summary of uncertainty calculations for selected safety related instrument functions. This information is provided to assist the NRC in reviewing the proposed relocation of instrument trip setpoints from the Technical Specifications to a licensee controlled document.
Based on the information provided in Enclosure 2, PSEG determined that the proposed license amendment does not involve a significant hazards consideration pursuant to 10 CFR 50.92(c) and that the changes are exempt from environmental review pursuant to the provisions of 10 CFR 51.22(c)(9). Further,the PSEG Fl eet Review Committee reviewed this LAR and determined that operation of Hope Creek in accordance with the proposed changes will not endanger the health and safety of the public.
PSEG requests approval and issuance of this proposed LAR by June 30, 2025 , to support implementation prior to the Hope Creek refueling outage scheduled for Fall 2025. PSEG further requests a 180-day implementation delay period following LAR approval to complete implementation activities.
If there are any questions or if additional information is needed, please contact Mr. Bria n Thomas at brian.thomas@pseg.com.
LR-N24-0029 10 CFR 50.90 Page 3
I declare under penalty of perjury that the foregoing is true and correct.
Executed on 5 /zo I 'U::I (Date)
Z4P Robert DeNight Site Vice President Hope Creek Generating Station
Enclosures:
Enclosure 1: Contents of the Hope Creek Improved Technical Specifications Submittal Enclosure 2: Hope Creek Improved Technical Specifications Submittal, Volumes 1 through 17 Enclosure 3: Licensee Identified Changes That May Require Technical Branch Review Enclosure 4: Disposition of Existing License Amendment Requests Enclosure 5: Regulatory Commitments Enclosure 6: List of Required Updated Final Safety Analysis Report (UFSAR) Descriptions For TSTF-500 Enclosure 7: Proposed Revisions to Hope Creek Renewed Facility Operating License NPF-57
Attachments:
Attachment 1 - Hope Creek Major System Differences from NUREG-1433 BWR/4 Plant Design Attachment 2 - Hope Creek Generating Station Instrument Setpoint Summary Report
cc: Administrator, Region I, NRC Mr. J. Kim, NRC Project Manager, Salem & Hope Creek NRC Senior Resident Inspector, Hope Creek Ms. Ann Pfaff, Manager NJBNE LR-N24-0029 LAR H24-02
ATTACHMENT 1
HOPE CREEK GENERATING STATION IMPROVED TECHNICAL SPECIFICATIONS SUBMITTAL
HOPE CREEK MAJOR SYSTEM DIFFERENCES FROM NUREG- 1433 BWR/4 PLANT DESIGN
(7 TOTAL PAGES, INCLUDING COVER SHEETS)
LR-N24 -0029 LAR H24-02
ATTACHMENT 1 Hope Creek Major System Differences from NUREG-1433 BWR/4 Plant Design
Table of Contents
Overview .........................................................................................................................2 Comparison of Hope Creek System Design to the ISTS System Design ....................... 2 Reactor Protection System (RPS) Instrumentation .....................................................2 Low Pressure Emergency Core Cooling System (ECCS) ...........................................3 Safety Auxiliaries Cooling System (SACS) ................................................................. 3 Station Service Water System (SSWS) .......................................................................4 Filtration Recirculation and Ventilation System (FRVS) ..............................................4 AC Electrical Power System ........................................................................................5 AC Electrical Power Distribution System .....................................................................5 References ......................................................................................................................6
LR-N24 -0029 LAR H24-02
HOPE CREEK MAJOR SYSTEM DIFFERENCES FROM NUREG-1433 BWR/4 PLANT DESIGN
Overview The purpose of this attachment is to assist the NRC staff's review of the Hope Creek Generating Station (Hope Creek ) Improved Technical Specifications (ITS) Conversion license amendment request (LAR). The technical discussion provided herein is for information use only to aid in understanding the Hope Creek specific design as compared to the BWR/4 plant design incorporated into NUREG -1433, Rev. 5.0, "Standard Technical Specifications, General Electric BWR/4 Plants ," (ISTS) and is not intended to be used to make decisions regarding safety or approval of the ITS Conversion LAR. This document addresses the following systems , summarizing the difference between the plant specific system design and the system design configuration associated with the ISTS:
- Reactor Protection System (RPS) Instrumentation
- Low Pressure Emergency Core Cooling System (ECCS) ,
- Safety Auxiliaries Cooling System (SACS),
- Station Service Water System (SSWS)
- Filtration Recirculation and Ventilation System (FRVS),
- AC Electrical Power System, and
- AC Electrical Power Distribution System.
Comparison of Hope Creek System Design to the ISTS System Design
Reactor Protection System (RPS) Instrumentation
The ISTS is based on a standard General Electric BWR/4 RPS instrument design. The Hope Creek RPS design is similar to the standard BWR/4 plant design with the exception of the power range neutron monitoring (PRNM) instrumentation and associated power supplies. The Average Power Range Monitor (APRM) System in the BWR/4 standard plant design is divided into two groups of channels with three APRM channel inputs to each trip system. The system is designed to allow one channel in each trip system to be bypassed. Any one APRM channel in a trip system can cause the associated trip system to trip.
The Hope Creek RPS PRNM Sy stem consists of the General Electric -Hitachi (GEH) digital Nuclear Measurement Analysis and Control (NUMAC) System. The PRNM System , in part, was installed to resolve the core stability solution using the Detect and Suppress Solution - Confirmation Density (DSS -CD) methodology as described in Reference 1 and includes an Oscillation Power Range Monitor - Upscale RPS trip.
The PRNM upgrade replaced the existing analog APRM sub-system of the Neutron Monitoring System with the digital NUMAC PRNM System and included a 120 V inverter system and PRNMS electrical power monitoring assemblies to isolate the PRNMS buses from the non-Class 1E power supply in the event of an abnormal
A1-2 LR-N24 -0029 LAR H24-02
voltage or frequency condition. The APRM channel design is a digital design consisting of a four channel APRM configuration whereby each channel uses one-fourth of the total local power range monitor detectors. The APRM functions in each logic channel are the same as the standard BWR/4 design; however four 2-out-of-4 voter logic channels are included in the Hope Creek design. Each APRM provides inputs to all four of the 2-out-of-4 voter logic channels. Outputs from two voter logic channels supply inputs to each of two Reactor Protection System (RPS) trip system divisions.
Low Pressure Emergency Core Cooling System (ECCS)
The ISTS is based on a standard General Electric BWR/4 low pressure ECCS design that consists of two CS subsystems, with one 100% flow CS pump in each subsystem and two LPCI subsystems, with two 100% flow LPCI pumps in each sub system, resulting in a total of four low pressure ECCS injection/spray subsystems. Each CS pump injects into a separate and independent core spray header. Each LPCI subsystem injects into the reactor recirculation loop discharge lines downstream of the reactor recirculation pump discharge valves. Long term cooling is provided by two residual heat removal (RHR) heat exchangers, one in each LPCI loop. The shutdown cooling (SDC) mode of RHR is provided by a single suction from the bottom of the RPV and discharge to the respective recirculation loops via the LPCI injection lines.
The Hope Creek ECCS design consists of two CS subsystems, with two 50% flow CS pumps in each subsystem, four separate and independent LPCI subsystems, with one 100% flow LPCI pump in each subsystem, resulting in six low pressure ECCS injection/spray subsystems. Each CS subsystem (2 pumps per subsystem) injects into a separate and independent core spray header similar to the standard BWR/4 design.
Each LPCI subsystem injects directly into the reactor core shroud.
In addition, t he Hope Creek LPCI System design does not include LPCI inverters to supply power to the LPCI inboard injection, minimum flow valves, or recirculation pump discharge valves. The Hope Creek ECCS design also does not include automatic closure of the recirculation pump discharge valves on a LPCI initiation signal because the LPCI subsystems inject directly into the reactor core shroud and do not interface with the discharge line of the recirculation pumps.The Hope Creek design also provides for long term cooling by two RHR heat exchangers in two LPCI subsystems (A and B). Hope Creek RHR SDC is provided by a single suction from the B reactor recirculation loop suction line and discharge to the respective recirculation loop via the SDC return lines.RHR pumps C and D can also be aligned to the A and B RHR heat exchangers to support SDC mode of the RHR System.
Safety Auxiliaries Cooling System (SACS)
The RHR Service Water (RHRSW) System in the ISTS is based on a standard General Electric BWR/4 design that is exclusively used for cooling the RHR heat exchangers.
The RHRSW System consists of two RHRSW subsystems, with two RHRSW pumps and one common heat exchanger in each subsystem.The RHRSW System is an open system that takes suction from the ultimate heat sink and discharges to the plant discharge canal. Depending on plant specific flow requirements, each RHRSW
A1-3 LR-N24 -0029 LAR H24-02
subsystem may require one or both RHRSW pumps to provide adequate heat removal capability to the associated RHRSW heat exchanger . Also, the ISTS includes a Specification for the Diesel Generator Standby Service Water (SSW) System. The DG SSW System in the standard BWR/4 design is a stand-alone cooling system that provide cooling water for the removal of heat from the applicable DGs. The DGs are the only components served by the DG SSW System.
The Hope Creek SACS is a closed loop cooling water system that resembles a pressurized water reactor (PWR) Component Cooling Water (C CW) System design and is not a stand-alone cooling system for the RHR System. Additionally, the Hope Creek design does not include a stand-alone cooling system for the emergency diesel generators (EDGs). T he Hope Creek SACS is designed to provide cooling water for the RHR System heat exchangers, EDG coolers, FRVS recirculation units, Engineered Safety Feature (ESF) room coolers, and other non-ESF equipment. The Hope Creek SSWS provides cooling, via the closed loop SACS, to the RHR exchangers, the EDGs, and other safety related components similar to the PWR CCW System as specified in NUREG-1431 (Westinghouse ISTS 3.7.7).
The Hope Creek SACS consists of two independent and redundant subsystems. Each subsystem is made up of a header, two pumps, a suction source, valves, piping, two 50% capacity heat exchangers, and associated instrumentation. O ne SACS pump in each subsystem is required to support the minimum cooling requirements during the initial phase of a design basis loss of coolant accident (LOCA). During the LOCA long term containment cooling mode or a loss of offsite power, any two of four SACS pumps operating provides sufficient cooling to satisfy the minimum requirements to achieve and maintain safe shutdown.
Station Service Water System (SSWS)
The Plant Service Water (PSW) System in the ISTS is based on a standard General Electric BWR/4 design and is an open system that takes suction from the ultimate heat sink and discharges to the plant discharge canal. Each of two PSW subsystems consists of a header, two pumps, a suction source, valves, piping and associated instrumentation. Either of the two subsystems is capable of providing the required cooling capacity to support the required systems with one pump operating.
The Hope Creek SSWS is similar in design to the standard PSW System. However, due to the SSWS heat load assumptions in the plant accident analyses, o ne SSWS pump in each subsystem is required to support the minimum cooling requirements of the SACS in the initial phase of a design basis LOCA. During the LOCA long term containment cooling mode or a loss of offsite power, any two of four SSWS pumps operating provides sufficient cooling to satisfy the minimum requirements of the SACS.
Filtration Recirculation and Ventilation System (FRVS)
ISTS is based on a standard General Electric BWR/4 Standby Gas Treatment (SGT)
System design that consists of t wo fully redundant 100% subsystems, each with its own set of ductwork, dampers, charcoal filter train, and controls.
A1-4 LR-N24 -0029 LAR H24-02
Each charcoal filter train consists of a demister or moisture separator, a n electric heater, a prefilter, a high efficiency particulate air (HEPA) filter, a charcoal adsorber, a second HEPA filter, and a centrifugal fan.
The Hope Creek design has FRVS comprised of two ventilation units and six recirculation units.Each ventilation unit and recirculation unit consists of its own set of ductwork, dampers, filtration, and controls.
Each FRVS recirculation unit consists of a centrifugal fan, a demister,a HEPA filter, a charcoal adsorber, and a second HEPA filter.Each FRVS ventilation unit consists of a centrifugal fan, a charcoal adsorber, and a HEPA filter. The ventilation units do not have demisters, and there are no HEPA filters ahead of the carbon adsorbers because the ventilation units are downstream of the recirculation units containing demisters and HEPA filters.
AC Electrical Power System
The ISTS is based on a single plant design with two redundant Class 1E electrical power trains/subsystems with two independent circuits between the offsite transmission network and the Class 1E Electrical Power System and two independent emergency diesel generators (EDGs) and a third EDG that acts as swing EDG between the two ECCS trains/subsystems. This design supports 10 CFR 50, Appendix A, General Design Criterion (GDC) 17.
The Hope Creek Class 1E AC Electrical Power System design consists of four redundant and independent AC electrical power distribution channels (i.e.,
subsystems). Electrical power distribution channels are referred in the Hope Creek improved Technical Specifications (ITS) as electrical power distribution subsystems.
Two qualified offsite circuits are provided between the transmission network and the onsite Class 1E AC Electrical Power System, with each capable of supplying all four AC electrical power distribution subsystems. Station service transformer (SST) A normally provides power to subsystems A and C and SST B normally provides offsite power to subsystems B and D. Each AC electrical power distribution subsystem can automatically transfer to the alternate offsite circuit. The onsite power source for the AC electrical power distribution subsystems consists of a dedicated EDG for each of the four subsystem s. For mechanical separation, safety related components (e.g.,
ECCS injection/spray subsystems) are grouped into two mechanical divisions with two AC electrical power distribution subsystems per mechanical division.
AC Electrical Power Distribution System
The ISTS is based on a single plant design with two redundant Class 1E electrical power distribution trains/subsystems with each train consisting of 4.16 kV buses, 480 V load center (LC) and motor control center (MCC) buses, two 125 V DC buses, and four 120 V vital AC buses (two per train).
The Hope Creek Class 1E Electrical Power Distribution System design consists of four channels (or subsystems) of AC, AC instrument, and 125 VDC buses and two channels (or subsystems) of 250 VDC buses. Safety analyses assume worst case single failure
A1-5 LR-N24 -0029 LAR H24-02
is the loss of a 125 VDC battery in one electrical power distribution channel (subsystem). The design does not include separate and independent 125 VDC electrical distribution channels (i.e., subsystems) for the EDGs . At Hope Creek, each Class 1E 125 VDC electrical power distribution subsystem supports its respective EDG. The HPCI and Reactor Core Isolation Cooling (RCIC) Systems include separate 250 VDC electrical power distribution channels (i.e., subsystems); Channels A and B, respectively.
References
- 1. General Electric Hitachi Licensing Topical Report NEDO-33075, GE Hitachi Boiling Water Reactor Detect and Suppress Solution - Confirmation Density, Rev. 7, June 2011 (non-Proprietary version).
A1-6 LR-N24-0029 LAR H24-02
ATTACHMENT 2
HOPE CREEK GENERATING STATION IMPROVED TECHNICAL SPECIFICATIONS SUBMITTAL
HOPE CREEK GENERATING STATION INSTRUMENT SETPOINT
SUMMARY
REPORT
(24 TOTAL PAGES, INCLUDING COVER SHEETS)
Hope Creek Generating Station Instrument Setpoint Summary Report
Revision 0
May 2024
Prepared By: Bruce Crabbs - See SAP Order Operation 80134504-0700 Date: 4/24/2024 EXCEL Services Corporation
Reviewed By: Jeff Schaeffer - See SAP Order Operation 80134504-0700 Date: 4/30/ 2024 PSEG Design Engineering
Approved By: Audrey Baricko - See SAP Order Operation 80134504-0700 Date: 5/2/2024 PSEG Design Engineering Manager
Hope Creek Generating Station Instrument Setpoint Summary Report
Table of Contents
- 1. Introduction ............................................................................................................. 3
- 2. Purpose ................................................................................................................... 3
- 3. Scope ....................................................................................................................... 4
- 4. Setpoint Methodology ............................................................................................ 4
- 5. Discussion .............................................................................................................. 6
- 6. References ............................................................................................................ 23
Rev. 0 Page 2 of 23 May 2024 Hope Creek Generating Station Instrument Setpoint Summary Report
- 1. Introduction
The Hope Creek Generating Station (HCGS) Reactor Protection System (RPS), Primary and Secondary Containment Isolation Actuation Instrumentation, Emergency Core Cooling System (ECCS) and Reactor Core Isolation Cooling (RCIC) System Instrumentation, Anticipated Trip Without Scram (ATWS) Recirculation Pump Trip (RPT) and End of Cycle (EOC) RPT Instrumentation, Control Rod Block Instrumentation, Radiation Monitoring Instrumentation, and Feedwater Main Turbi ne Trip Actuation Instrumentation Specifications of the current technical specifications (CTS) each contain Trip Setpoint and Allowable Value (AV) parameters for the associated functional units.
PSEG Nuclear LLC (PSEG) proposes to relocate instrument trip setpoints from the Technical Specifications to a licensee-controlled document consistent with NRC NUREG -1433, Standard Technical Specifications (STS) for General Electric BWR/4 Plants, and Technical Specifications Task Force (TSTF) Traveler TSTF-493, Clarify Application of Setpoint Methodology for LSSS Functions, Revision 4, in the Improved Technical Specifications (ITS) Conversion license amendment request.
PSEG is not proposing any change to HCGS instrument setpoints associated with limiting safety system settings (LSSS) because of relocation of instrument trip setpoints from the Technical Specifications to a licensee-controlled document nor is PSEG proposing any change to the HCGS current licensing basis instrument setpoint methodology used tocalculate these setpoints as part of the conversion to the ITS for instrument functions specified in the Technical Specifications. The summary channel performance uncertainty calculations for the instrument Functions specified in the current technical specifications will continue to be calculated consistent with the current HCGS instrument setpoint control program .
Under the heading Adoption of TSTF-493. Option A without Changes to Setpoint Values, in the Notice of Availability of the Models for Plant-Specific Adoption of Technical Specifications Task Force Traveler TSTF-493, Revision 4, "Clarify Application of Setpoint Methodology for LSSS Functions, the notice states: Since no setpoint changes are being proposed, there is no need to provide the setpoint methodology for review or to provide any full or summary calculations. H owever, this report provides a summary of the HCGS instrument setpoint methodology and a summary of selected instrument uncertainty calculations to support the NRC review of the ITS Conversion license amendment request.
- 2. Purpose
The purpose of this Instrument Setpoint Summary Report is to provide a summary description of the HCGS instrument setpoint methodology used to determine the Limiting Trip Setpoint (LTSP), Nominal Trip Setpoint (NTSP), Allowable Value (AV), As -Found Tolerance (AFT), and As-Left Tolerance (ALT) for the RPS, Primary and Secondary Containment Isolation Actuation Instrumentation, ECCS and RCIC System Instrumentation, ATWS RPT and EOC RPT Instrumentation, Control Rod Block Instrumentation, Radiation Monitoring Instrumentation, and Feedwater Main Turbine Trip Actuation Instrumentation Functions specified in the Technical Specifications in support of relocating the NTSPs from the Technical Specifications consistent with NUREG-1433 and TSTF-493.
Rev. 0 Page 3 of 23 May 2024 Hope Creek Generating Station Instrument Setpoint Summary Report
- 3. Scope
The scope of this report is applicable to the Trip Setpoint, Allowable Value, and As -Found / As -
Left data values and their respective source documents for various functional units appearing in the aforementioned HCGS CTS instrumentation sections .
- 4. Setpoint Methodology
The HCGS setpoint methodology for safety related instrumentation, including instruments protecting LSSS, is described in PSEG Technical Standard, Technical Standard Instrument Setpoint Calculations, (Ref. 1).The methods outlined in this instrument setpoint methodology technical standard are used to validate instrument performance for the selected values or to develop new setpoint values based on process limits. The instrument setpoint methodology technical standard is required for safety related instrument trip functions and other instrument trip functions (safety or non-safety) cited in the plant Technical Specifications (TSs ). Changes to an existing setpoint is accomplished in accordance with the plant setpoint change control process as documented in the plant engineering design control and instrument setpoint change procedures.
As discussed in HCGS UFSAR Section 1.8.1.105, the stations instrument setpoint methodology was originally based on the guidance in NRC Regulatory Guide (RG) 1.105, Instrument Setpoints, Rev. 1, for the determination of instrument Trip S etpoints, Allowable Values, and instrument loop accuracy. Although HCGS is not committed to the latest revision of RG 1.105, HCGS instrument setpoint methodology practices are consistent with later revisions of this guidance and their supporting industry standards. The HCGS instrument setpoint methodology technical standard is based upon RG 1.105, Rev. 2, which endorses the original version of ISA S67.04 1982, Setpoints for Nuclear Safety -Related Instrumentation, developed to further define setpoint methodology requirements.HCGS setpoint control procedures cite either ISA -
S67.04-1994 which is endorsed by RG 1.105, Setpoints for Safety -Related Instrumentation, Rev. 3, or later versions of the ISA standard. These documents define a framework for ensuring that setpoints for nuclear safety -related instrumentation are established and maintained within specified limits; HCGS instrument setpoint methodology practices follow the intent of these later versions of the ISA code, primarily ISA-S67-04-1998 (method 2).
The initial AVs and NTSPs were developed using the General Electric (GE) methodology described in NEDC-31336 (Ref. 2).The GE instrument setpoint methodology has been approved by the US Nuclear Regulatory Commission (NRC) as NEDC-31336P-A. According to this methodology, the setpoints are calculated from the Analytical Limit (AL), or from the AV if there is no AL , using a top-down approach and margin is calculated by methodology :
The margin between the AL and the final NTSP is at least equal to, and generally greater than that needed, to meet the 95% probability requirement of NRC RG 1.105 Rev. 3.
Rev. 0 Page 4 of 23 May 2024 Hope Creek Generating Station Instrument Setpoint Summary Report
The GE calculated values for AVs and NTSPs were used by PSEG as inputs to the LSSS related calculations. The objectives of the HCGS LSSS related calculations were to validate that adequate margin exists between analytical limits and AV s and NTSPs under both normal and accident conditions. The calculations also determined recalibration and calibration values used to assess an instrument or channels operability status when performing surveillance tests (Channel Calibration, Channel Check, and Channel Functional Test). The terms recalibration tolerance and calibration tolerance are equivalent , respectively, to the terms AFT and ALT specified in NUREG-1433. If the as found data exceeds the recalibration tolerances, or AFT limits, then the instrument or channel must be reset to a value within the calibration tolerance or ALT limits as specified in the HCGS Technical Specifications.
The Calibration Tolerance for devices other than transmitters is equal to the vendor accuracy (VA). For transmitters, the Calibration Tolerance is equal to the VA multiplied by the square root of two if VA is less than 1% span. If VA exceeds 1%, Calibration Tolerance equals the SRSS combination of VA and 1% span.
The Recalibration Tolerance for devices other than transmitters is the SRSS combination of the Calibration Tolerance and the Calibration Effect (M&TE errors). For transmitters, the Recalibration Tolerance is the SRSS combination of the Calibration Tolerance and the smaller of VA or 1% span. The Recalibration Tolerance does not include projected drift and is more conservative than the AFT described in TSTF-493.
The NTSP is the limiting setting used for the channel trip setpoint considering a combination of effects including instrument total accuracy, drift, calibration, primary element accuracy, and process measurement accuracy. The NTSP is also the least conservative value (with an As Left Tolerance) to which the channel must be reset at the conclusion of periodic testing to ensure that the analytical limit (AL) will not be exceeded during an anticipated operational occurrence (AOO) or accident before the next periodic surveillance or calibration. The AV is the LSSS and ensures the automatic protective action will correct an abnormal situation before a safety limit is exceeded. The difference between the AL and the NTSP and the AV and the NTSP is identified in the setpoint calculations as the total allowance (TA). The total loop allowance (TLA) value is derived from the NTSP considering all credible instrument errors, including instrument drift, associated with an instrument channel. Instrument AL margin and AV margin are derived from the difference between the TA and the TLA (TA - TLA = Margin). For instruments associated with a safety analysis limit (SAL), each summary performance uncertainty calculation shows zero or positive AL and AV margin. Changes to the NTSP under licensee control due to a change in the TLA can only reduce the margin between the NTSP and the AV. Thus, the margin of the LSSS to the SAL is preserved because any change to the instrument AV will require prior NRC approval.
Both AFT and ALT are provided in the surveillance test procedures and these values are calculated in the PSEG specific calculations. R esetting an instrument channel to within the ALT value will ensure that the AL is not exceeded during an AOO or accident before the next periodic surveillance or calibrationinterval. Since it is impractical to physically set an instrument channel to an exact value, a tolerance is established around the NTSP and is identified in the HCGS calculations as the Calibration Tolerance (i.e., ALT). To determine when a channel or instrument requires resetting, the setpoint calculations include a Recalibration Tolerance (i.e.,
AFT). If the instrument or channel is found outside the recalibration tolerance then the channel is reset to within the calibration tolerance. Thus, NTSP adjustment is then considered successful if the as-left instrument setting is within the ALT (i.e., a range of values around the NTSP).
Rev. 0 Page 5 of 23 May 2024 Hope Creek Generating Station Instrument Setpoint Summary Report
Plant testprocedures require the performer to stop and report a condition whenever the AFT is exceeded or where the signal response is considered sluggish. Following discovery of this condition, procedures provide a formal method of evaluating an instrument channel to determine if it remains operable and requires initiation of a notification in plant corrective action program (CAP ) screening process.
Based on HCGS setpoint methodology being utilized to create new setpoint calculations and to revise existing setpoint calculations consistent with original General Electric methodologies and industry standards such as NRC RG 1.105, Rev. 3 and ISA -S67.04-1994, there is sufficient technical support for removal of Trip Setpoints from the HCGS Technical Specifications.
- 5. Discussion
Section 5 summarizes examples of the application of the HCGS setpoint methodology as it appears in HCGS setpoint calculations. The setpoint calculations exhibited in this report were selected as they represent functions that are impacted by the conversion to a 24 M onth Fuel Cycle (MFC) and have recently been revised to support this project. The current revision of the setpoint calculation reflects a comparison of the drift value from the previous revision of the calculation and the analyzed drift value appearing in the applicable drift calculations generated for the 24 MFC conversion. The methodology utilized in the setpoint calculations displayed in this report represent the same methodology in the setpoint calculations of other HCGS safety related instrument functions.
5.1. Reactor Protection System Instrumentation - Scram Discharge Volume Water Level-High
The function of this instrument loop is to measure Scram Discharge Volume Water Level. The scram discharge volume receives the water displaced by the motion of the control rod drive pistons during a reactor scram. Should this volume fill up to a point where there is insufficient volume to accept the displaced water at pressures below 65 psig, control rod insertion would be hindered.
This instrument loop consists of a Gould PD-3218 Transmitter and Rosemount 510DU Trip Unit.
Reactor Protection System Instrumentation - Scram Discharge Volume Water Level -
High
Term Definition Value Units Notes AV Allowable Value 86.5 in H2O
NTSP Nominal Trip Setpoint 80.5 in H2O Scram Discharge Water Level - High
TA Trip Allowance 6 in H2O
Rev. 0 Page 6 of 23 May 2024 Hope Creek Generating Station Instrument Setpoint Summary Report
TA = lAV-NTSPl TA = l86.5 in H2O - 80.5 in H2Ol
Margin Allowable Value Margin 4.39 in H2O Margin = TA - TLA Margin = 6 in H2O - 1.61 in H2O As TA is greater than TLA, acceptable margin does exist. Further calculations are not required.
AL Analytical Limit 99.375 in H2O
TA Total Allowance 18.88 in H2O TA = lAL-NTSPl TA = l99.375 in H2O - 80.5 in H2O l
Margin Analytical Limit Margin 17.27 in H2O Margin = TA - TLA Margin = 18.88 in H2O - 1.61 in H2O As TA is greater than TLA, acceptable margin does exist. The loop is conditionally acceptable.
TLA = Total Loop Allowance - A combination of effects including instrument total accuracy, drift, calibration, primary element accuracy, and process measurement accuracy.
NTSP = Nominal Trip Setpoint - Term for setpoint as used in General Electric instru ment Setpoint Methodology, Report No, NEDC -31336, October 1986.
Rev. 0 Page 7 of 23 May 2024 Hope Creek Generating Station Instrument Setpoint Summary Report
Reactor Protection System Instrumentation - Scram Discharge Volume Water Level -
High
(Note: Not to Scale)
ANALYTICAL LIMIT (INCR.) =
99.375 in H2O ANALYTICAL LIMIT MARGIN = 17.27 in H2O
ALLOWABLE VALUE (INCR.) =
86.5 in. H2O ALLOWABLE VALUE MARGIN = 4.39 in H2O
TLA to AL = 1.61 in H2O
TLA to AV = 1.61 in H2O
SETPOINT = 80.5 in H2O (Increasing)
RESET SETPOINT = 80.04 in H2O (Decreasing)
Rev. 0 Page 8 of 23 May 2024 Hope Creek Generating Station Instrument Setpoint Summary Report
Reactor Protection System Instrumentation - Scram Discharge Volume Water Level - High
Instrument Tolerances, Total Accuracies, and Total Loop Allowances
Calibration Tolerance (As Left) +/- 0.06 mADC
+/- 0.35% span Transmitter Recalibration Tolerance (As Found) +/- 0.07 mADC
+/- 0.43% span Total Accuracy +/- 1.03% span Calibration Tolerance (As Left) +/- 0.20% span
+/- 0.03 mADC Trip Unit Recalibration Tolerance (As Found) +/- 0.28% span
+/- 0.05 mADC Total Accuracy +/- 0.13% span Positive +1.82% span TLA +1.61 in H2O Negative -1.82% span
-1.61 in H2O
Setpoint Conversion, Reset and Analysis
Nominal Trip Setpoint 80.5 in H2O 18.57 mADC Reset Setpoint 80.04 in H2O 18.49 mADC SDIV High Allowable Value 86.5 in H2O Water Level Total Allowance 6.0 in H2O Allowable Value Margin 4.39 in H2O
Analytical Limit 99.375 in H2O Total Allowance 18.88 in H2O Analytical Limit Margin 17.27 in H2O
Rev. 0 Page 9 of 23 May 2024 Hope Creek Generating Station Instrument Setpoint Summary Report
5.2. Emergency Core Cooling System Actuation Instrumentation - Automatic Depressurization System - Reactor Vessel Water Level - Low, Level 3 (Permissive)
The function of this instrument loop is to measure the Nuclear Boiler Reactor Water Level for Low Water Level (Level 3) and to send a confirmatory signal to the ADS initiating logic.
This instrument loop includes two redundant Rosemount 1153DB4P differential pressure transmitters, which send signals to associated Rosemount 510DU MTU. The MTUs provide the Reactor Low Water Level confirmatory signal to the ADS initiating logic when reactor vessel level decreases to level 3.
Emergency Core Cooling System Actuation Instrumentation - Automatic Depressurization System - Reactor Vessel Water Level - Low, Level 3 (Permissive)
Term Definition Value Units Notes AV Allowable 11 in H2O Value
TA Total Allowance 1.5 in H2O TA = NTSP - AV = 12.5 in H2O - 11 in H2O = 1.5 in H2O
Margin Allowable 0.06 in H2O Margin = TA - TLANormal Value Margin As TA is more than Normal Condition TLA (1.44 in H2O), acceptable margin does exist. Further calculations are not required Margin = TA - TLA = 1.5 in H2O - 1.44 in H2O =
0.06 in H2O AL Analytical Limit 7.5 in H2O
TA Total Allowance 5.0 in H2O TA = NTSP - AL = 12.5 in H2O - 7.5 in H2O = 5 in H2O
Margin Analytical Limit 3.06 in H2O Margin = TA - TLAAccident Margin As TA is more than Accident Condition TLA (1.94 in H2O), acceptable margin does exist.
The loop is conditionally acceptable.
Margin = TA - TLA = 5 in H2O - 1.94 in H2O =
3.06 in H2O
Rev. 0 Page 10 of 23 May 2024 Hope Creek Generating Station Instrument Setpoint Summary Report
TLA = Total Loop Allowance - A combination of effects including instrument total accuracy, drift, calibration, primary element accuracy, and process measurement accuracy.
NTSP = Nominal Trip Setpoint - Term for setpoint as used in General Electric instrument Setpoint Methodology, Report No, NEDC -31336, October 1986.
Rev. 0 Page 11 of 23 May 2024 Hope Creek Generating Station Instrument Setpoint Summary Report
Emergency Core Cooling Sy stem Actuation Instrumentation - Automatic Depressuriz ation Sy stem - Reactor Vessel Water Level - Low , Level 3 (Permissive)
(Note: Not to Scale)
ANALY TICAL LIMIT (INCR.) = N/A
ALLOWABLE VALUE (INCR.) = N/A
RESET POINT (INCR.) = 12.8 in H2O
SETPOINT = 12.5 in H2O
TLA (Normal) = 1.44 in H2O
AV Margin = 0.06 in H2O ALLOWABLE VALUE (DECR.) = 11.0 in H2O TLA (Accident) = 1.94 in H2O
AL Margin = 3.06 in H2O
ANALY TICAL LIMIT (DECR.) = 7.5 in H2O
Rev. 0 Page 12 of 23 May 2024 Hope Creek Generating Station Instrument Setpoint Summary Report
Emergency Core Cooling System Actuation Instrumentation - Automatic Depressurization System - Reactor Vessel Water Level - Low, Level 3 (Permissive)
Instrument Tolerances, Total Accuracies, and Total Loop Allowances
Calibration Tolerance (As Left) 0.06 mADC Transmitter Recalibration Tolerance (As Found) 0.07 mADC Total Accuracy - Normal Conditions 0.89% span Total Accuracy - Accidental Conditions 3.21% span Calibration Tolerance (As Left) 0.03 mADC Master Trip Unit Recalibration Tolerance (As Found) 0.05 mADC Total Accuracy 0.13% span Positive +3.40% span TLA (Normal +1.44 in H2O Condition) Negative -3.40% span
-1.44 in H2O Positive +4.59% span TLA (Accident +1.94 in H2O Condition) Negative -4.59% span
-1.94 in H2O
Setpoint Conversion, Reset and Analysis
Nominal Trip Setpoint 12 .5 in H2O 7.33 mADC Reset Setpoint 12.8 in H2O 7.41 mADC Reactor Vessel Allowable Value 11 in H2O Water Level - Low Total Allowance 1.5 in H2O (Level 3) Allowable Value Margin 0.06 in H2O
Analytical Limit 7 .5 in H2O Total Allowance 5 in H2O Analytical Limit Margin 3.06 in H2O
Rev. 0 Page 13 of 23 May 2024 Hope Creek Generating Station Instrument Setpoint Summary Report
5.3. Isolation Actuation Instrumentation - Main Steam Line Isolation - Condenser Vacuum -
Low
The Main Condenser Low Vacuum signal could indicate a leak in the condenser.
Initiation of automatic closure of the MSIVs and steam line drain valves will prevent excessive loss of reactor coolant and the release of significant amounts of radioactive material to the environment.
Four redundant pressure transmitters and associated trip units monitor the main condenser vacuum. When low vacuum is detected in the main condenser by either trip system (A or B), the Primary Containment and Reactor Vessel Isolation Control System initiates closure of all main steam line isolation and drain valves .
Isolation Actuation Instrumentation - Main Steam Line Isolation - Condenser Vacuum -
Low
Term Definition Value Units Notes AL Analytical Limit 7.00 inHg Vac
AV Allowable Value 7.60 inHg Vac
SP Trip Setpoint (Tech Spec) 8.50 inHg Vac Eo = l(30 inHg Vac - Pin)/ PSpanl x 16 15.47 mADC mADC + 4 mADC Eo=l(30 inHg Vac - 8.5 inHg Vac)/ 30 inHg Vacl x 16 mADC + 4 mADC =
15.47 mADC
The current reset is at 15.39 mAdc or Trip Setpoint (Reset) 8.64 inHg Vac g=suum= =
The=swihaset=
ip=point=from=0.5%
ansmirent=ss=
s=x=16=mAaC=AaC =
=
15.4T=mAaC AaC===15.39=
aC =
=
E o===l(g=s==m Sn l
- 15. = aC = aC=aC =
=
m ===30=ig=s= -=[ o= =4=mAaC)
= = = mAaC]m span l
ig=s = =AaC= -=4AaC)
AaC=xg=sl===8.64=ine
= = = c
=
Rev. 0 Page 14 of 23 May 2024 Hope Creek Generating Station Instrument Setpoint Summary Report
TLA = Total Loop Allowance - A combination of effects including instrument total accuracy, drift, calibration, primary element accuracy, and process measurement accuracy.
NTSP = Nominal Trip Setpoint - Term for setpoint as used in General Electric instrument Setpoint Methodology, Report No, NEDC -31336, October 1986.
Rev. 0 Page 15 of 23 May 2024 Hope Creek Generating Station Instrument Setpoint Summary Report
Isolation Actuation Instrumentation - Main Steam Line Isolation - Condenser Vacuum -
Low
Substantiate the Margin between the Analytical Limit/Allowable Value and the Setpoint Term Definition Value Units Notes Total Loop Allowance-TLANormal Normal +/-0.4 1 inHg Vac
Total Loop Allowance-TLAAccident Accident +/-0. 44 inHg Vac
AL Analytical Limit 7.00 inHg Vac
AV Allowable Value 7.60 inHg Vac
SP Process Trip Setpoint 8.50 inHg Vac (Tech Spec)
Margin- Normal Conditions 0.49 inHg Vac Margin = SP - (AV +
TLANormal)
Margin = 8.50 inHg -
(7.60 inHg + 0.41 inHg) = 0.49 inHg Vac
Margin- Accident Conditions +/-1.0 6 inHg Vac TLAAccident)
Margin = 8.50 inHg -
(7.00 inHg + 0. 44 inHg) = 1.0 6 inHg Vac
A positive margin exists between the Analytical Limit and the Setpoint including Accident Uncertainties. In addition a positive margin exists between the Allowable Value and the Setpoint including Normal Uncertainties; therefore, the calculated Setpoints are acceptable.
TLA = Total Loop Allowance - A combination of effects including instrument total accuracy, drift, calibration, primary element accuracy, and process measurement accuracy.
NTSP = Nominal Trip Setpoint - Term for setpoint as used in General Electric instrument Setpoint Methodology, Report No, NEDC-31336, October 1986.
Rev. 0 Page 16 of 23 May 2024 Hope Creek Generating Station Instrument Setpoint Summary Report
Isolation Actuation Instrumentation - Main Steam Line Isolation - Condenser Vacuum -
Low
(Note: Not to Scale)
ANALYTICAL LIMIT = 7.0 inHg sm =
Te=IcICION=iIMIT =
iOtABisAir== 7.6 inHg M n = = Vacuum
i s
SETPOINT + TLA = 8.09 inHg Vacuum
SETPOINT = isacuum=/=
15.4T=mAaC =
RESET POINT = 8.64 inHg Vacuum /
15.39 mADC
OPERATING POINT = 2.5 inHg A /
26.92 inHg Vacuum
Rev. 0 Page 17 of 23 May 2024 Hope Creek Generating Station Instrument Setpoint Summary Report
Isolation Actuation Instrumentation - Main Steam Line Isolation - Condenser Vacuum -
Low
Instrument Tolerances, Total Accuracies, and Total Loop Allowances
Calibration Tolerance (As Left) +/- 0.06 mADC Transmitter Recalibration Tolerance (As Found) +/- 0.07 mADC Total Accuracy (Normal Conditions) +/- 0.82% span Total Accuracy (Accident Conditions) +/- 1.02% span Calibration Tolerance (As Left) +/- 0.20% span
+/- 0.03 mADC Trip Unit Recalibration Tolerance (As Found) +/- 0.28% span
+/- 0.05 mADC Total Accuracy +/- 0.20% span TLA Normal Positive and Negative Loop Allowance +/- 1.35% span
+/- 0.41 inHg Vac Margin +/- 0.49 inHg Vac TLA Accident Positive and Negative Loop Allowance +/- 1.48% span
+/- 0.44 inHg Vac Margin +/- 1.06 inHg Vac
Rev. 0 Page 18 of 23 May 2024 Hope Creek Generating Station Instrument Setpoint Summary Report
5.4. Isolation Actuation Instrumentation Setpoints - RHR System Shutdown Cooling Mode Isolation - Reactor Vessel (RHR Cut -in Permissive) Pressure - High
The function of this instrument loop is to measure Reactor Vessel Pressure and sends a Reactor High Pressure Signal to the RHR Isolation Shutdown Cooling Interlocks. This instrument loop includes a Rosemount 1153GB9 transmitter, Rosemount 510DU Master Trip Unit, and Rosemount 510DU Slave Trip Unit
Isolation Actuation Instrumentation Setpoints - RHR System Shutdown Cooling Mode Isolation - Reactor Vessel (RHR Cut -in Permissive) Pressure - High
Term Definition Value Units Notes AV Allowable Value 102 PSIG SP Setpoint 82 PSIG
1.22 VDC Setpoint / Transmitter Span
- Signal Span + Signal Zero
- 4 VDC
+ 1 VDC = 1.22 VDC
TLA Total Loop Allowance 14.94 PSIG (Normal, pos)
Normal Positive
TLA(Normal, neg) Total Loop Allowance -14.94 PSIG Normal Negative
TLA(Accident, pos) Total Loop Allowance 30.16 PSIG Accident Positive
TLA(Accident, neg) Total Loop Allowance -30.16 PSIG Accident Negative
lAV -SPl Allowable Value - 20 PSIG lAV -SPl = 102 PSIG - 82 PSIG =
Setpoint 20 PSIG As lAV-SPl is greater than TLA(Normal,pos), acceptable margin does exist. Further calculations are not required
TLA = Total Loop Allowance - A combination of effects including instrument total accuracy, drift, calibration, primary element accuracy, and process measurement accuracy.
NTSP = Nominal Trip SetPoint - Term for setpoint as used in General Electric instrument Setpoint Methodology, ReportNo, NEDC-31336, October 1986.
Rev. 0 Page 19 of 23 May 2024 Hope Creek Generating Station Instrument Setpoint Summary Report
Isolation Actuation Instrumentation Setpoints - RHR System Shutdown Cooling Mode Isolation - Reactor Vessel (RHR Cut -in Permissive) Pressure - High
Term Definition Value Units Notes AL Analytical Limit 115 PSIG
lAL-SPl Analytical Limit - 33 PSIG lAL-SPl = 115 PSIG - 82 PSIG =
Setpoint 33 PSIG As lAL-SPl is greater than TLA(Accident,pos), acceptable margin does exist. Further calculations are not required
Reset Reset Differential 74.5 PSIG Reset differential is calculated as Differential the minimum differential, as expressed in percent of span, given by the device manufacturer.
Reset differential is adjustable between 0.5 and 7.5% of input span.
Therefore "reset Differential" =
0.5% span Reset Differential = SP - (0.5%
- Input Span)
Reset Differential = 82 PSIG -
(0.5%
- Input Span)
Reset Point = 1.22 VDC - (0.5%
- 4 VDC) = 1.20 VDC
TLA = Total Loop Allowance - A combination of effects including instrument total accuracy, drift, calibration, primary element accuracy, and process measurement accuracy.
NTSP = Nominal Trip Setpoint - Term for setpoint as used in General Electric instrument Setpoint Methodology, Report No, NEDC -31336, October 1986.
Rev. 0 Page 20 of 23 May 2024 Hope Creek Generating Station Instrument Setpoint Summary Report
Isolation Actuation Instrumentation Setpoints - RHR System Shutdown Cooling Mode Isolation - Reactor Vessel (RHR Cut -in Permissive) Pressure - High (Note: Not to Scale)
ANALYTICAL LIMIT (INCR.) = 115 PSIG ANALYTICAL LIMIT MARGIN = 2.84 PSIG
ALLOWABLE VALUE (INCR.) = 102 PSIG
ALLOWABLE VALUE MARGIN = 5.06 PSIG
TLADBE = 30.16 PSIG
TLANORMAL = 14.94 PSIG
SETPOINT = 82 PSIG
RESET SETPOINT = 74.5 PSIG
Rev. 0 Page 21 of 23 May 2024 Hope Creek Generating Station Instrument Setpoint Summary Report
Isolation Actuation Instrumentation Setpoints - RHR System Shutdown Cooling Mode Isolation - Reactor Vessel (RHR Cut -in P ermissive) Pressure - High
Instrument Tolerances, Total Accuracies, and Total Loop Allowances
Calibration Tolerance (As Left) 0.35% span 0.06 mADC Transmitter (N078A) Recalibration Tolerance (As Found) 0.43% span 0.07 mADC Total Accuracy Normal 0.55% span Total Accuracy Accident 1.83% span Calibration Tolerance (As Left) 0.35% span 0.06 mADC Transmitter (N078B/C/D) Recalibration Tolerance (As Found) 0.43% span 0.07 mADC Total Accuracy Normal 0.58% span Total Accuracy Accident 1.84% span Master Trip Unit Total Accuracy 0.13% span Calibration Tolerance (As Left) 0.28% span 0.01 VDC Slave Trip Unit Recalibration Tolerance (As Found) 0.40% span 0.02 VDC Total Accuracy 0.19% span Total Loop Allowance Random(Normal) 1.00% span 14.94 PSIG Total Loop Allowance Random(Accident) 2.01% span 30.16 PSIG Positive(Normal) 1.00% span TLA 14.94 PSIG Negative(Normal) -1.00% span
-14.94 PSIG Positive(Accident) 2.01% span 30.16 PSIG Negative(Accident) -2.01% span
-30.16 PSIG
Rev. 0 Page 22 of 23 May 2024 Hope Creek Generating Station Instrument Setpoint Summary Report
- 6. References
- 1. PSEG Nuclear Technical Standard, HC.DE-TS.ZZ-1001, Instrument Setpoint Calculations for Hope Creek Generating Station, Revision 0 , March 3, 2006.
- 2. NEDC-31336, General Electric Instrument Setpoint Methodology October 1986.
Rev. 0 Page 23 of 23 May 2024