ML20036D444

Part 02 - Final Safety Analysis Report (Rev. 4) - Part 02 - Tier 02 - Chapter 08 - Electric Power - Sections 08.01 - 08.04

ML20036D444
Person / Time
Site:	NuScale
Issue date:	01/16/2020
From:	Bergman T NuScale
To:	Office of Nuclear Reactor Regulation
Cranston G
References
NUSCALESMRDC, NUSCALESMRDC.SUBMISSION.10, NUSCALEPART02.NP, NUSCALEPART02.NP.4
Download: ML20036D444 (135)

Text

e Standard Plant Certification Application ter Eight tric Power T 2 - TIER 2 4

2020 uScale Power LLC. All Rights Reserved

COPYRIGHT NOTICE document bears a NuScale Power, LLC, copyright notice. No right to disclose, use, or copy any of information in this document, other than by the U.S. Nuclear Regulatory Commission (NRC), is horized without the express, written permission of NuScale Power, LLC.

NRC is permitted to make the number of copies of the information contained in these reports ded for its internal use in connection with generic and plant-specific reviews and approvals, as well he issuance, denial, amendment, transfer, renewal, modification, suspension, revocation, or ation of a license, permit, order, or regulation subject to the requirements of 10 CFR 2.390 regarding rictions on public disclosure to the extent such information has been identified as proprietary by cale Power, LLC, copyright protection notwithstanding. Regarding nonproprietary versions of e reports, the NRC is permitted to make the number of additional copies necessary to provide ies for public viewing in appropriate docket files in public document rooms in Washington, DC, and where as may be required by NRC regulations. Copies made by the NRC must include this copyright ce in all instances and the proprietary notice if the original was identified as proprietary.

APTER 8 ELECTRIC POWER. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .8.1-1 8.1 Introduction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.1-1 8.1.1 Utility Power Grid and Offsite Power System Description . . . . . . . . . . . . . . . . . . . . . 8.1-1 8.1.2 Onsite Power System Description . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.1-2 8.1.3 Safety-Related Loads. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.1-4 8.1.4 Design Bases . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.1-4 8.2 Offsite Power System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.2-1 8.2.1 Description . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.2-1 8.2.2 Switchyard . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.2-1 8.2.3 Analysis . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.2-2 8.3 Onsite Power Systems . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.3-1 8.3.1 Alternating Current Power Systems . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.3-1 8.3.2 Direct Current Power Systems . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.3-21 8.3.3 References . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.3-40 8.4 Station Blackout . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.4-1 8.4.1 Station Blackout Analysis Assumptions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.4-1 8.4.2 Station Blackout Analysis and Results. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.4-1 8.4.3 Station Blackout Coping Equipment Assessment. . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.4-2 8.4.4 Station Blackout Procedures and Training . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.4-3 2 i Revision 4

le 8.1-1: Acceptance Criteria and Guidelines for Electric Power Systems . . . . . . . . . . . . . . . . . 8.1-7 le 8.3-1: Onsite Alternating Current Power System Component Data Nominal Values . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.3-43 le 8.3-2: Backup Diesel Generator Nominal Loads . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.3-44 le 8.3-3: Highly Reliable Direct Current Power System Major Component Data Nominal Values . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.3-45 le 8.3-4: Highly Reliable Direct Current Power System - Common Nominal Loads . . . . . . . 8.3-46 le 8.3-5: Highly Reliable Direct Current Power System - Module Specific Nominal Loads . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.3-47 le 8.3-6: Highly Reliable DC Power System Alarms and Indications. . . . . . . . . . . . . . . . . . . . . . 8.3-49 le 8.3-7: Highly Reliable Direct Current Power System Failure Modes and Effects Analysis. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.3-50 le 8.3-8: Normal Direct Current Power System Major Component Data Nominal Values . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.3-60 le 8.3-9: FSAR Cross Reference for the Conditions of Applicability and NRC SER Limitations and Conditions for TR-0815-16497-P-A . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.3-62 le 8.3-10: FSAR Cross Reference for the EDSS Augmented Provisions in TR-0815-16497-P-A. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.3-64 le 8.4-1: Station Blackout Sequence of Events. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.4-4 2 ii Revision 4

re 8.3-1: Station Single Line Diagram . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.3-65 re 8.3-2a: 13.8kV and Switchyard System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.3-66 re 8.3-2b: 13.8kV and Switchyard System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.3-67 re 8.3-3a: Medium Voltage Alternating Current Electrical Distribution System . . . . . . . . . . . . 8.3-68 re 8.3-3b: Medium Voltage Alternating Current Electrical Distribution System . . . . . . . . . . . . 8.3-69 re 8.3-4a: Low Voltage Alternating Current Electrical Distribution System . . . . . . . . . . . . . . . . 8.3-70 re 8.3-4b: Low Voltage Alternating Current Electrical Distribution System . . . . . . . . . . . . . . . . 8.3-71 re 8.3-4c: Low Voltage Alternating Current Electrical Distribution System . . . . . . . . . . . . . . . . 8.3-72 re 8.3-4d: Low Voltage Alternating Current Electrical Distribution System . . . . . . . . . . . . . . . . 8.3-73 re 8.3-4e: Low Voltage Alternating Current Electrical Distribution System . . . . . . . . . . . . . . . . 8.3-74 re 8.3-4f: Low Voltage Alternating Current Electrical Distribution System . . . . . . . . . . . . . . . . 8.3-75 re 8.3-4g: Low Voltage Alternating Current Electrical Distribution System . . . . . . . . . . . . . . . . 8.3-76 re 8.3-4h: Low Voltage Alternating Current Electrical Distribution System . . . . . . . . . . . . . . . . 8.3-77 re 8.3-4i: Low Voltage Alternating Current Electrical Distribution System . . . . . . . . . . . . . . . . 8.3-78 re 8.3-4j: Low Voltage Alternating Current Electrical Distribution System . . . . . . . . . . . . . . . . 8.3-79 re 8.3-4k: Low Voltage Alternating Current Electrical Distribution System . . . . . . . . . . . . . . . . 8.3-80 re 8.3-4l: Low Voltage Alternating Current Electrical Distribution System . . . . . . . . . . . . . . . . 8.3-81 re 8.3-4m: Low Voltage Alternating Current Electrical Distribution System . . . . . . . . . . . . . . . . 8.3-82 re 8.3-4n: Low Voltage Alternating Current Electrical Distribution System . . . . . . . . . . . . . . . . 8.3-83 re 8.3-4o: Low Voltage Alternating Current Electrical Distribution System . . . . . . . . . . . . . . . . 8.3-84 re 8.3-4p: Low Voltage Alternating Current Electrical Distribution System . . . . . . . . . . . . . . . . 8.3-85 re 8.3-4q: Low Voltage Alternating Current Electrical Distribution System . . . . . . . . . . . . . . . . 8.3-86 re 8.3-4r: Low Voltage Alternating Current Electrical Distribution System . . . . . . . . . . . . . . . . 8.3-87 re 8.3-4s: Low Voltage Alternating Current Electrical Distribution System . . . . . . . . . . . . . . . . 8.3-88 re 8.3-4t: Low Voltage Alternating Current Electrical Distribution System . . . . . . . . . . . . . . . . 8.3-89 re 8.3-4u: Low Voltage Alternating Current Electrical Distribution System . . . . . . . . . . . . . . . . 8.3-90 re 8.3-4v: Low Voltage Alternating Current Electrical Distribution System . . . . . . . . . . . . . . . . 8.3-91 re 8.3-4w: Low Voltage Alternating Current Electrical Distribution System . . . . . . . . . . . . . . . . 8.3-92 re 8.3-4x: Low Voltage Alternating Current Electrical Distribution System . . . . . . . . . . . . . . . . 8.3-93 re 8.3-4y: Low Voltage Alternating Current Electrical Distribution System . . . . . . . . . . . . . . . . 8.3-94 re 8.3-4z: Low Voltage Alternating Current Electrical Distribution System . . . . . . . . . . . . . . . . 8.3-95 re 8.3-5a: Backup Power Supply System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.3-96 2 iii Revision 4

re 8.3-5b: Backup Power Supply System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.3-97 re 8.3-6: Highly Reliable Direct Current Power System (Common). . . . . . . . . . . . . . . . . . . . . . . 8.3-98 re 8.3-7a: Highly Reliable Direct Current Power System (Module Specific) . . . . . . . . . . . . . . . . 8.3-99 re 8.3-7b: Highly Reliable Direct Current Power System (Module Specific) . . . . . . . . . . . . . . . 8.3-100 re 8.3-8a: Normal Direct Current Power System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.3-101 re 8.3-8b: Normal Direct Current Power System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.3-102 re 8.3-8c: Normal Direct Current Power System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.3-103 re 8.3-8d: Normal Direct Current Power System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.3-104 re 8.3-8e: Normal Direct Current Power System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.3-105 re 8.3-8f: Normal Direct Current Power System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.3-106 re 8.4-1: Station Blackout Reactor Pressure Vessel Water Level Above Top of Active Fuel. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.4-5 re 8.4-2: Station Blackout Reactor Pressure Vessel Pressure . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.4-6 re 8.4-3: Station Blackout Containment Vessel Pressure . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.4-7 re 8.4-4: Station Blackout Containment Vessel Temperature. . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8.4-8 2 iv Revision 4

Introduction 1 Utility Power Grid and Offsite Power System Description For the NuScale Power Plant, the offsite power system includes a switchyard and one or more connections to a transmission grid, micro-grid, or dedicated service load. The interface between the onsite alternating current (AC) power system and the offsite power system is at the switchyard side of the first intertie (motor-operated disconnect) on the high side of the main power transformers.

The NuScale Power Plant is designed with passive, safety-related systems for safe shutdown, core and spent fuel assembly cooling, containment isolation and integrity, and reactor coolant pressure boundary integrity. This design does not depend on onsite or offsite AC electrical power, including that from the transmission grid, for safe operation.

Therefore, the availability of AC electrical power from an offsite power source does not impact the ability to achieve and maintain safety-related functions. A loss of voltage, degraded voltage condition, or other electrical transient on the nonsafety-related AC power systems does not have an adverse effect on the ability to achieve and maintain safe-shutdown conditions.

The NuScale Power Plant non-reliance on electrical power accommodates siting the facility at locations where an offsite transmission grid is not available or where the offsite transmission grid reliability is less than what normally would be required for siting and operation of a typical reactor design. Accordingly, the NuScale design supports a connection to a transmission grid through one or more offsite transmission circuit connections, or to a micro-grid, or to both. A micro-grid consists of a group of interconnected loads and distributed energy resources within clearly defined electrical boundaries that act as a single controllable entity that can operate either connected or not connected to the transmission grid.

As described in Section 8.2 and Section 8.3, the NuScale design supports an exemption from General Design Criteria (GDC) 17 and 18.

As described in Section 8.3, the normal source of electrical power to the NuScale Power Plant electrical loads is provided by the operating power module main generators through connections to the switchyard rather than from an offsite transmission grid connection. For NuScale Power Plant operations as planned, connection to an offsite transmission grid is used only to distribute the power generated by the plant to electricity consumers and is not relied upon to perform plant safety functions. Thus, the transmission grid is more representatively described for the NuScale Power Plant as an electrical load rather than a power source. The effects of grid stability as a result of a loss of one or more NPMs is discussed in Section 8.2.

2 8.1-1 Revision 4

The onsite electrical power systems include AC power systems and direct current (DC) power systems. Also included is a backup power supply system (BPSS) consisting of diesel generators and an auxiliary AC power source (AAPS).

2.1 Onsite Alternating Current Power System The onsite AC power systems are nonsafety-related, non-Class 1E and include the following:

• Normal AC power system 13.8 kV and Switchyard system (EHVS) with nominal bus voltage of 13.8 kV Medium voltage AC electrical distribution system (EMVS) with nominal bus voltage of 4.16kV Low voltage AC electrical distribution system (ELVS) with nominal bus voltages of 480V and 120V

• BPSS Backup diesel generators (BDGs) with nominal output voltage of 480V AAPS with nominal output voltage of 13.8kV Power to the onsite AC power systems is normally provided by the operating NuScale Power Module (NPM) main generators connected to the EHVS (see Figure 8.3-2a and Figure 8.3-2b). Medium-voltage and low-voltage plant auxiliary and service loads are supplied through the unit auxiliary transformers, which also are connected to the EHVS.

Power that is generated in excess of plant load requirements is supplied to the switchyard through the main power transformers. Either a transmission grid connection or the AAPS also may provide power to the onsite AC power system through the EHVS during periods when the NPMs are not operating. Whether power is provided from the main generators, a transmission grid, or the AAPS, the power flow to plant loads is from the EHVS main generator buses to the EMVS through the unit auxiliary transformers.

The EHVS voltage is reduced by the unit auxiliary transformers to the EMVS nominal bus voltage of 4.16kV. The EMVS is depicted in Figure 8.3-3a and Figure 8.3-3b. The EMVS buses distribute power to the loads at 4.16kV.

The EMVS voltage is reduced by the station service transformers to the ELVS nominal bus voltage of 480 V from which power is distributed to the 480 V plant loads. The ELVS is depicted in Figure 8.3-4a through Figure 8.3-4z.

A loss of voltage or degraded voltage condition on the AC power systems does not adversely affect the performance of plant safety-related functions. See Section 8.3 for additional detail.

The BPSS provides backup sources of AC electrical power when the normal AC power sources are not available. This condition would occur if none of the NPMs were 2 8.1-2 Revision 4

BDGs and an AAPS as described in Section 8.3. Neither the BDGs nor the AAPS is relied upon to achieve and maintain plant safety-related functions. Although BPSS capability is included in the NuScale design, non-reliance on AC power eliminates the need for an alternate AC power source to meet the station blackout (SBO) coping requirements. An evaluation of SBO for the NuScale design is provided in Section 8.4.

The NuScale Power Plant is designed with the capability to operate independently of a connection to an external transmission grid. The island mode design feature provides nonsafety and not risk-significant operating flexibility that is not relied upon to satisfy safety-related functions. Island mode capability, combined with the availability of the BPSS power generation sources, reduces the likelihood of a complete loss of AC power.

The BDGs provide backup electrical power to selected equipment loads. The primary BDG load is the highly reliable DC power system (EDSS). The BDG portion of the BPSS and its connections to the ELVS is shown in Figure 8.3-4a through Figure 8.3-4z. The ELVS equipment and circuits downstream of these motor control centers are used to route the power to the selected loads.

The AAPS is capable of providing power to plant auxiliary and service loads during periods when other AC power sources are not available. This capability includes providing electrical power for initial startup of an NPM (i.e., black start), and for normal shutdown and cooldown of NPMs in the unlikely event of a simultaneous loss of the operating main generators and a transmission grid connection (if provided). The AAPS is connected directly to the EHVS 13.8kV generator buses through its generator circuit breaker as shown in Figure 8.3-2a and Figure 8.3-2b.

Refer to Section 8.3.1 for a detailed description of the onsite AC electrical power systems.

2.2 Onsite Direct Current Power System The onsite DC power systems are non-Class 1E and nonsafety-related. These systems include the following:

• highly reliable DC power system (EDSS)

• normal DC power system (EDNS)

The EDSS is comprised of two DC subsystems which provide a continuous, failure-tolerant source of 125 Vdc power to assigned plant loads during normal plant operation and for a specified minimum duty cycle following a loss of AC power. The EDSS is failure tolerant because any piece of EDSS equipment can fail or be removed from service without adversely affecting EDSS functional capability. The EDSS common plant subsystem (EDSS-C) serves the plant common loads which have functions not specific to a single NPM. The EDSS module-specific plant subsystem (EDSS-MS) consists of up to 12 separate and independent DC electrical power supply systems, one for each individual NPM. The EDSS-MS for a NPM provides electrical power for the module protection system and other loads associated with that NPM. Figure 8.3-6, Figure 8.3-7a, and Figure 8.3-7b provide the simplified one line diagrams of the EDSS-C 2 8.1-3 Revision 4

The EDNS shown in Figure 8.3-8a through Figure 8.3-8f is not required for nuclear safety. The EDNS contains both 250 Vdc and 125 Vdc batteries and is shared between the NPMs. EDNS provides both DC power and AC power (via inverters at 120/208 Vac) to nonsafety-related loads that support functions related to investment protection and power generation. The EDNS battery chargers are supplied from the ELVS.

See Section 8.3.2 for a detailed description of the onsite DC electrical power systems.

3 Safety-Related Loads The NuScale design does not include safety-related loads and does not rely on electrical power or operator action to achieve and maintain safe shutdown. The safety-related systems actuate by passive means and their continued operation relies on natural mechanisms based on fundamental physical and thermodynamic principles (e.g., gravity; natural circulation; convective, radiative, and conductive heat transfer; condensation; and evaporation).

In the NuScale design, safety-related functions are assured upon a loss of electrical power to the loads. Safety-related SSC do not require electric power to perform plant safety-related functions during a design basis event.

4 Design Bases 4.1 Offsite Power System The design bases for the offsite power system, if provided, are site-specific and are described in Section 8.2.

4.2 Onsite Power System The EDSS is designed as a non-Class 1E system whose functions are nonsafety-related and not risk-significant. Although the EDSS is not safety-related, it is designed as a highly reliable DC power system to support important plant loads, as described in Section 8.3.2. Common cause failures are minimized by the EDSS design. Reliability is provided by designing double redundancy into the batteries and battery chargers for each EDSS channel or division. Independence of the redundant equipment is maintained by applying appropriate physical separation and electrical isolation measures between the non-Class 1E and Class 1E equipment. The EDSS-C sub-system supplies electrical power to common plant loads, the EDSS-MS subsystems are not designed to be shared between NPMs.

The EDSS battery design provides for 24 or 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> duty cycles based upon the required function of the connected loads.

The EDNS is designed as a non-Class 1E system whose functions are nonsafety-related and not risk-significant. The EDNS batteries are designed to provide DC power and AC 2 8.1-4 Revision 4

The EHVS is designed as a non-Class 1E system whose functions are nonsafety-related and not risk-significant. The EHVS is designed with the capability for the EHVS buses to be connected, through the switchyard, to any onsite main generator for operation in island mode. The EHVS equipment is physically separated from safety related circuits and is not located near safety-related components.

The EMVS is designed as a non-Class 1E system whose functions are nonsafety-related and not risk-significant. The EMVS circuits are physically separated from safety circuits throughout the plant and EMVS equipment is not located near safety-related components.

The ELVS is designed as a non-Class 1E system whose functions are nonsafety-related and not risk-significant.The ELVS design includes upstream fault protection to the pressurizer heater circuits.

The BPSS is designed to provide electrical power to the NuScale Power Plant when AC power is not available. The BPSS is a non-Class 1E system whose functions are non-safety related and not risk-significant. The AAPS and the BDGs are designed to automatically start on a loss of 13.8 kV bus voltage and to be manually connected to provide backup AC power to the affected loads.

4.3 Regulatory Requirements and Guidance Table 8.1-1 summarizes the extent to which Nuclear Regulatory Commission (NRC) requirements and guidance relevant to electrical systems are applied in the design of NuScale electrical systems. Conformance with NRC requirements and guidance also is summarized in Section 1.9 and Section 3.1. In general, electrical systems are designed in accordance with the requirements and guidance with exceptions or clarifications noted below:

• The design of the NuScale offsite, onsite AC, and onsite DC electrical systems conforms to GDC 2, GDC 4, and GDC 5 to the extent described in Section 8.2, Section 8.3.1, and Section 8.3.2. As described in Section 3.1, the NuScale design supports an exemption from GDC 17, GDC 18, and GDC 33.

• The plant design complies with a set of principal design criteria in lieu of GDC 34, 35, 38, 41, and 44, as described in Section 3.1.4. The principal design criteria do not include requirements for electric power systems.

• The electrical penetration assembly (EPA) design conforms to GDC 50.

Section 8.3.1.2.5 addresses the EPA electrical design requirements. Sections 3.8.2 and 6.2.1 address the mechanical integrity requirements of GDC 50.

• The NuScale design does not rely on pressurizer heaters to establish and maintain natural circulation in shutdown conditions. Accordingly, the NuScale design supports an exemption from the 10 CFR 50.34(f)(2)(xiii) (TMI Item II.E.3.1) requirement to provide pressurizer heater power supply and associated motive and control power interfaces to establish and maintain natural circulation in shutdown conditions.

2 8.1-5 Revision 4

provide emergency power sources and qualified motive and control power connections for such valves are not technically relevant to the NuScale design. The NuScale design supports an exemption from the portions of the rule which require vital power buses for pressurizer level indicators.

• The extent to which the design of NuScale electrical systems conforms to 10 CFR 50.55a(h) is described in Section 8.3.1 and Section 8.3.2.

• The NuScale Power Plant design conforms to the requirements of 10 CFR 50.63 for a light water reactor to have the capability to withstand an SBO for a specified duration and recover from an SBO as defined in 10 CFR 50.2. Additional details regarding conformance with 10 CFR 50.63 are described in Section 8.4.

• The 10 CFR 50.65(a)(4) assessment is applied to NuScale electrical system SSC that (1) are determined to meet the 10 CFR 50.65(b) criteria, and (2) a risk-informed evaluation process has shown to be significant to public health and safety.

Section 17.6 describes the maintenance rule (10 CFR 50.65) program.

• NUREG-0737 includes guidance related to TMI Item II.E.3.1 (codified in 10 CFR 50.34(f)(2)(xiii)), and TMI Item II.G.1 (codified in 10 CFR 50.34(f)(2)(xx)). As described above for 10 CFR 50.34(f)(2), the NuScale design supports exemptions from these regulations.

• Portions of NUREG/CR-0660 relevant to the NuScale electrical systems are considered as reference only, consistent with NuScale DSRS Section 8.1.

Conformance with TMI items, including those addressed in this NUREG, is described in Section 1.9.

• SECY-90-016 pertains to evolutionary advanced light water reactor (ALWR) designs and is not directly applicable to passive plant designs. As a passive ALWR design, the NuScale electrical system design conforms to the passive plant guidance of SECY-94-084, Section F.

• SECY-91-078 pertains to evolutionary ALWR designs and is not directly applicable to passive plant designs. As a passive ALWR design, the NuScale electrical system design conforms to the passive plant guidance of SECY-94-084, Section G.

• The design of NuScale electrical systems conforms to the Commission-approved positions in Sections F and G of SECY-94-084 related to passive plant electrical systems.

• The evaluation of NuScale electrical systems under the regulatory treatment of nonsafety systems (RTNSS) process conforms to SECY-94-084, Section A, as modified in SECY-95-132 and subsequently established in NUREG-0800, Section 19.3. The portion of SECY-95-132 that modifies the RTNSS process description in SECY-94-084, Section A, is applied as guidance to the NuScale nonsafety-related electrical systems. Specifically, the evaluation of NuScale electrical systems under the RTNSS process conforms to Attachment1 (Item A) of SECY-95-132.

2 8.1-6 Revision 4

cale Final Safety Analysis Report Criteria Title Applicable Section (Note 1) Remarks 8.2 8.3.1 8.3.2 8.4 Offsite Onsite Onsite DC Station Power AC Power Power Blackout System System System 0 CFR 50, Appendix A, General Design Criteria for Nuclear Plants DC 2 Design bases for protection against A A §8.2 - ADAMS Accession natural phenomena No. ML090260039 DC 4 Environmental and dynamic effects A A §8.2 - ADAMS Accession design bases No. ML090260039 DC 5 Sharing of structures, systems, and A A §8.2 - ADAMS Accession components Nos. ML11133A334 and ML090260039 DC 17 Electric power systems The NuScale design supports an exemption from GDC 17.

DC 18 Inspection and testing of electric The NuScale design supports an power systems exemption from GDC 18.

DC 33 Reactor coolant makeup The NuScale design supports an exemption from GDC 33.

DCs 34, 35, 38, 41, 44 Residual heat removal, emergency The plant design complies with a core cooling, containment heat set of principal design in lieu of removal, containment atmosphere these GDC, as described in Section cleanup, cooling water 3.1.4.

DC 50 Containment design basis A A The electrical design requirements for electrical penetration assemblies are included in Section 8.3.1.

egulations (10 CFR 50 and 10 CFR 52) 0 CFR 50.34 Contents of applications; technical information 10 CFR 50.34(f)(2)(v) Additional Three Mile Island This requirement is not applicable (TMI)-related requirements (Item to the NuScale electric power I.D.3) systems, which are not safety-related.

10 CFR 50.34(f)(2)(xiii) Additional TMI-related requirements The NuScale design supports an Introduction (Item II.E.3.1) exemption from 10CFR50.34(f)(2)(xiii).

cale Final Safety Analysis Report Criteria Title Applicable Section (Note 1) Remarks 8.2 8.3.1 8.3.2 8.4 Offsite Onsite Onsite DC Station Power AC Power Power Blackout System System System

. 10 CFR 50.34(f)(2)(xx) Additional TMI-related requirements The NuScale design does not (Item II.G.1) include pressurizer relief valves or block valves, and the the design supports an exemption from the pressurizer level indicator portion of 10CFR50.34(f)(2)(xx).

0 CFR 50.55a(h) Codes and standards A A 0 CFR 50.63 Loss of all alternating current power G A 0 CFR 50.65(a)(4) Requirements for monitoring the A A A Development and implementation effectiveness of maintenance at of the Maintenance Rule program is nuclear power plants discussed in Section 17.6.

0 CFR 52.47(b)(1) Contents of applications; technical A A A A Paragraph (b)(1), as it relates to information ITAAC (for design certification) sufficient to assure that the SSC in this area of review will operate in accordance with the certification.

0 CFR 52.80(a) Contents of applications; additional N/A for NuScale, this rule pertains to technical information applications referencing an early site permit or a standard design certification.

egulatory Guides (RGs) egulatory Guide 1.6 - March 1971 Safety Guide 6 - Independence G G Between Redundant Standby (Onsite)

Power Sources and Between Their Distribution Systems egulatory Guide 1.32 - Revision 3, Criteria for Power Systems for Nuclear G As it relates to the EDSS; see arch 2004 Power Plants Section 8.3.2 egulatory Guide 1.41 - March 1973 Preoperational Testing of Redundant G As it relates to EDSS; see Section Onsite Electric Power Systems to 8.3.2 Verify Proper Load Group Assignments Introduction egulatory Guide 1.47 - Revision 1, Bypassed and Inoperable Status This guidance does not apply to the ebruary 2010 Indication for Nuclear Power Plant NuScale electric power systems, Safety Systems which are not safety-related.

cale Final Safety Analysis Report Criteria Title Applicable Section (Note 1) Remarks 8.2 8.3.1 8.3.2 8.4 Offsite Onsite Onsite DC Station Power AC Power Power Blackout System System System egulatory Guide 1.53 - Revision 2, Application of the Single-Failure G G As it relates to the EDSS; see ovember 2003 Criterion to Safety Systems Section 8.3.2 egulatory Guide 1.63 - Revision 3, Electric Penetration Assemblies in G G The electrical design requirements ebruary 1987 Containment Structures for Nuclear for electrical penetration assemblies Power Plants (EPAs) with respect to RG 1.63 are included in Section 8.3.

egulatory Guide 1.68 - Revision 4, June Initial Test Programs for water-Cooled G G G As it relates to the EDSS; see 013 Nuclear Power Plants Section 8.3.2. See Section 8.2 as it relates to the offsite power system.

egulatory Guide 1.75 - Revision 3, Criteria for Independence of Electrical G G As it relates to the EDSS; see ebruary 2005 Safety Systems Section 8.3.2 egulatory Guide 1.81 - Revision 1, Shared Emergency and Shutdown G G EDSS-MS is not shared; sharing of nuary 1975 Electric Systems for Multi-Unit Nuclear EDSS-C meets the intent of the Power Plants guidance; see Section 8.3.2 egulatory Guide 1.106 - Revision 2, Thermal Overload Protection for Not applicable; the design does not ebruary 2012 Electric Motors on Motor-Operated include safety-related MOVs Valves egulatory Guide 1.118 - Revision 3, Periodic Testing of Electric Power and G G As it relates to the EDSS; see pril 1995 Protection Systems Section 8.3.2 egulatory Guide 1.128 Revision 2, Installation Design and Installation of G Applicability as described in ebruary 2007 Vented Lead-Acid Storage Batteries Reference 8.3-1 and Section 8.3.2 for Nuclear Power Plants egulatory Guide 1.129 - Revision 3, Maintenance, Testing, and G Applicability as described in eptember 2013 Replacement of Vented Lead-Acid Reference 8.3-1 and Section 8.3.2 Storage Batteries for Nuclear Power Plants egulatory Guide 1.153 - Revision 1, Criteria for Safety Systems G G §8.3.2 - Applies to EDSS to the ne 1996 extent described in Reference 8.3-1 egulatory Guide 1.155 - August 1988 Station Blackout G G G Limited to portions relevant to passive plant designs; see Section 8.4 Introduction egulatory Guide 1.160 - Revision 3, Monitoring the Effectiveness of G G ay 2012 Maintenance at Nuclear Power Plants

cale Final Safety Analysis Report Criteria Title Applicable Section (Note 1) Remarks 8.2 8.3.1 8.3.2 8.4 Offsite Onsite Onsite DC Station Power AC Power Power Blackout System System System egulatory Guide 1.204 - November Guidelines for Lightning Protection of G 005 Nuclear Power Plants egulatory Guide 1.206 - June 2007 Combined License Applications for G G G G Nuclear Power Plants (LWR Edition) egulatory Guide 1.212 - November Sizing of Large Lead-Acid Storage G As it relates to sizing VRLA batteries; 008 Batteries see Section 8.3.2 egulatory Guide 1.218 - April 2012 Condition-Monitoring Techniques for G G G Limited to cables determined to be Electric Cables Used in Nuclear Power within the scope of 10 CFR 50.65 Plants ranch Technical Positions (BTPs)

RP BTP 8-1 Requirements on Motor-Operated Not applicable; the design does not Valves in the ECCS Accumulator Lines include safety-related MOVs or ECCS accumulator lines RP BTP 8-2 Use of Onsite AC Power Sources for G As it relates to the non-Class 1E Peaking BDGs; see Section 8.3.1 RP BTP 8-3 Stability of Offsite Power Systems G RP BTP 8-4 Application of the Single Failure Not applicable; see Section 8.3.1 Criterion to Manually-Controlled and Section 8.3.2 Electrically-Operated Valves RP BTP 8-5 Supplemental Guidance for Bypass This BTP does not apply to NuScale and Inoperable Status Indication for electric power systems as these Engineered Safety Features Systems systems are not engineered safety features and are not relied on to support engineered safety features.

RP BTP 8-6 Adequacy of Station Electric Not applicable; See Section 8.2.3 Distribution System Voltages and Section 8.3.1 RP BTP 8-7 Criteria for Alarms and Indications Not applicable; no Class 1E Associated with Diesel-Generator Unit emergency diesel generators Bypassed and Inoperable Status RP BTP 8-8 Onsite (emergency diesel generators) Not applicable; with non-reliance and offsite power sources allowed on AC power, no technical Introduction outage time extensions specification operating restrictions for inoperable AC power sources

cale Final Safety Analysis Report Criteria Title Applicable Section (Note 1) Remarks 8.2 8.3.1 8.3.2 8.4 Offsite Onsite Onsite DC Station Power AC Power Power Blackout System System System RP BTP 8-9 Open Phase Conditions in Electric G G See Section 8.2 Power System UREG Reports UREG-0737 Clarification of TMI Action Plan See Section 8.1.4.3 Requirements UREG/CR-0660 Enhancement of Onsite Diesel G Reference only Generator Reliability ommission Papers (SECYs)

ECY-90-016 Evolutionary Light Water Reactor Not applicable Certification Issues and their Relationships to Current Regulatory Requirements, 1990 ECY-91-078 Electric Power Research Institute Not applicable Requirements Document and Additional Evolutionary Light Water Reactor (LWR) Certification Issues, 1991 ECY-94-084 Policy and Technical Issues Associated G G G G Used as guidance as described in with the RTNSS in Passive Plant Section 8.1.4.3 Designs, 1994 ECY-95-132 Policy and Technical Issues Associated G G G G Used as guidance as described in with the RTNSS in Passive Plant Section 8.1.4.3 Designs, 1995 RC Bulletins RC Bulletin 2012-01 (July 2012) Design Vulnerability in Electric G G See Section 8.2.

Power System

" denotes acceptance criteria, and "G" denotes guidance, applied in the design of NuScale electrical systems. No letter denotes "Not Applicable."

Introduction

1 Description For the NuScale Power Plant, the offsite power system includes the switchyard and one or more connections to a transmission grid, micro-grid, or dedicated service load. The interface between the onsite alternating current (AC) power system and the offsite power system is at the switchyard side of the first intertie (motor-operated disconnect) on the high side of the main power transformers (MPTs). The MPTs are included in the 13.8 kV and switchyard electrical system (EHVS), which is described in Section 8.3.1.

The passive design of the NuScale Power Plant does not rely on AC power and does not require an offsite power system to mitigate design basis events as described in Section 15.0.0 or to perform risk-significant functions. Accordingly, the NuScale design supports an exemption from GDC 17 and GDC 18. While this section provides the regulatory framework and a description of an offsite power system, the design of the switchyard and the connections to an offsite power system (if provided) are site-specific considerations.

During normal operations with at least one NuScale Power Module operating, the associated turbine generator is the source of power to the onsite AC power system as described in Section 8.3.1. A single turbine generator has sufficient capacity to meet the maximum expected total auxiliary AC load requirements for up to 12 NuScale Power Modules such that excess power is supplied to the offsite power system if one or more turbine generators are operating.

The onsite auxiliary AC power source may be used as the power source for the AC power system during startup if the NuScale Power Modules are not operating. Offsite power is a secondary source for plant startup or shutdown. If the auxiliary AC power source or a turbine generator is not available, the NuScale Power Plant is designed to backfeed power through the MPTs from an offsite power source for startup or shutdown loads. The NuScale Power Plant has the capability to operate independently from the offsite power system in island mode as discussed in Section 8.3.1.

2 Switchyard The design of the switchyard and the connections to an offsite power system are site-specific and are the responsibility of the combined license (COL) applicant.

Item 8.2-1: A COL applicant that references the NuScale Power Plant design certification will describe the site-specific switchyard layout and design, including offsite power connections, control and indication, characteristics of circuit breakers and buses, protective relaying, power supplies, lightning and grounding protection equipment, and conformance with General Design Criteria (GDC) 5.

2 8.2-1 Revision 4

3.1 Analysis of Grid Stability Item 8.2-2: A COL applicant that references the NuScale Power Plant design certification will describe the site-specific offsite power connection and grid stability studies, including the effects of grid contingencies such as the loss of the largest operating unit on the grid, the loss of one NuScale Power Module, and the loss of the full complement of NuScale Power Modules (up to 12). The study will be performed in accordance with the applicable Federal Energy Regulatory Commission, North American Electric Reliability Corporation, and transmission system operator requirements, including communication agreements and protocols.

3.2 Analysis of Offsite Power System Conformance with Regulatory Framework This section describes the extent to which the design of the offsite power system conforms to NRC requirements and guidance.

General Design Criteria 17 The NuScale design supports an exemption from the GDC 17 requirements for an offsite power system. The passive design of the NuScale Power Plant does not rely on onsite AC power and does not require an offsite power system to assure that specified acceptable fuel design limits and design conditions of the reactor coolant pressure boundary are not exceeded as a result of anticipated operational occurrences or to maintain core cooling or containment integrity in the event of postulated accidents, as discussed in Section 15.0.0. In addition, the offsite power system is not relied upon to provide power for risk-significant functions.

General Design Criteria 18 As described above, the NuScale design supports an exemption from GDC 17.

Accordingly, the design supports an exemption from the GDC 18 inspection and testing requirements.

General Design Criteria 33 The NuScale design supports an exemption from GDC 33, as described in Section 3.1.4.

General Design Criteria 34, 35, 38, 41, and 44 The plant design complies with a set of principal design criteria in lieu of these GDC, as described in Section 3.1.4. The principal design criteria do not include requirements for electric power systems.

10 CFR 50.63 The NuScale Power Plant conformance with 10 CFR 50.63 is described in Section 8.4.

2 8.2-2 Revision 4

The development and implementation of the maintenance rule (10 CFR 50.65) program, including the identification of structures, systems, and components that require assessment in accordance with 10 CFR 50.65(a)(4), is described in Section 17.6.

Regulatory Guide 1.218 (April 2012)

Regulatory Guide 1.218 provides guidance for monitoring the condition of cables that have been determined to fall within the scope of the maintenance rule (10 CFR 50.65).

The development and implementation of the maintenance rule program, including the identification of SSC that require assessment per 10 CFR 50.65(a)(4), is stated in Section 17.6.

Branch Technical Position 8-3 Revision 3 The performance of grid stability studies is site-specific and is addressed in Section 8.2.3.1.

Branch Technical Position 8-6 Revision 3 Branch Technical Position (BTP) 8-6 addresses the adequacy of offsite system voltages to Class 1E (safety-related) loads. The offsite power system does not supply power to Class 1E loads and does not support safety-related functions. Accordingly, BTP 8-6 is not applicable to the offsite power system.

Branch Technical Position 8-9 Revision 0 The BTP 8-9 addresses the effects of transmission grid open-phase conditions as identified in NRC Information Notice 2012-03 and NRC Bulletin 2012-01. This guidance involves protection from a common cause AC power failure due to open phase conditions in the offsite power sources that are credited for GDC 17 and the effect on onsite safety-related buses and safety-related loads. The offsite power system does not support safety-related functions. In addition, failures of the offsite power system, including open phase conditions or a station blackout, do not prevent the operation of safety-related functions.

If the offsite power system is supplying power to the onsite AC power system, the electrical isolation between the highly reliable DC power system and equipment with safety-related functions, which is described in Section 7.1.2, ensures that the open phase conditions described in BTP 8-9 would not prevent the performance of safety-related functions.

Regulatory Guide 1.32 Revision 3 Regulatory Guide 1.32 addresses design criteria for safety-related power systems. The NuScale Power Plant does not rely on an offsite power system to support or perform safety functions. Accordingly, Regulatory Guide 1.32 is not applicable to the offsite power system.

2 8.2-3 Revision 4

Item 8.2-3: A COL applicant that references the NuScale Power Plant design certification will describe the testing of the switchyard and the connections to an offsite power system, if provided, consistent with Regulatory Guide 1.68, Revision 4. The testing description will include the details of initial testing associated with degraded offsite power conditions.

SECY 94-084 and SECY 95-132 FSAR Section 17.4.3 describes the NuScale methodology to establish risk significance of SSC. The NuScale process for evaluating SSC against the RTNSS criteria is described in FSAR Section 19.3. This process did not identify safety-related or risk-significant loads for the offsite power system.

The lack of safety-related and risk-significant AC loads and the 72-hour SBO coping capability of the passive NuScale design as described in Section 8.4 obviate the need for an alternate AC power source or a safety-related emergency diesel generator, consistent with SECY 94-084 Parts F and G which were confirmed in SECY 95-132.

2 8.2-4 Revision 4

The onsite power systems provide power to the plant loads during all modes of plant operation. The onsite power systems include alternating current (AC) power systems and direct current (DC) power systems. The plant safety-related functions are achieved and maintained without reliance on electrical power; therefore, neither the AC power systems nor the DC power systems are required to be safety-related (Class1E). This conclusion is confirmed by the application of the evaluation methodology described in NuScale topical report TR-0815-16497-P-A (Reference 8.3-1). Table 8.3-9 provides a cross reference of the FSAR sections that demonstrate compliance with the conditions of applicability and the additional limitations in the NRC Safety Evaluation Report (SER) associated with this topical report.

The nonsafety-related onsite AC power systems are described in Section 8.3.1. The nonsafety-related DC power systems are described in Section 8.3.2. Structures, systems, and components (SSC) classification information for the onsite power systems is provided in Section 3.2.

1 Alternating Current Power Systems 1.1 System Description The onsite AC power systems distribute AC power to the onsite DC power systems (through battery chargers) and to the plant AC electrical loads during startup and shutdown, normal operation, and off-normal conditions. The NuScale Power Plant does not use nor include an emergency onsite AC power system. The onsite AC power systems are shared between the NuScale Power Modules (NPMs), and include the following:

• normal power system (Section 8.3.1.1.1) 13.8 kV and switchyard system (EHVS) with nominal bus voltage of 13.8 kV medium voltage AC electrical distribution system (EMVS) with nominal bus voltage of 4.16 kV low voltage AC electrical distribution system (ELVS) with nominal bus voltages of 480 V and 120 V

• backup power supply system (BPSS) (Section 8.3.1.1.2) backup diesel generators (BDGs) with nominal output voltage of 480 V auxiliary AC power source (AAPS) with nominal output voltage of 13.8 kV The normal source of onsite AC electrical power is from the operating NPM turbine generators (see Figure 8.3-2a and Figure 8.3-2b) through the EHVS generator buses.

The EHVS supplies the plant loads through the unit auxiliary transformers (UATs). The EHVS also supplies the switchyard through the main power transformers (MPTs), which are connected to the offsite transmission grid, a micro-grid (if the plant is not connected to a transmission grid), or both, as described in Section 8.2. Each NPM is designed to sustain a loss of external electrical load from full power while its associated turbine generator remains connected and capable of supplying plant electrical loads.

The loss of electrical load capability is not a safety-related function. If the NPMs are not 2 8.3-1 Revision 4

system is described in Section 8.2.

The UATs reduce the EHVS voltage from 13.8 kV to the EMVS nominal bus voltage of 4.16 kV. The EMVS is depicted in Figure 8.3-3a and Figure 8.3-3b. The power at the EMVS buses is distributed to large (nonsafety-related) pump motor loads and to the high-side terminals of the station service transformers (SSTs). The SSTs are the interface between the EMVS and the ELVS as shown in Figure 8.3-4a through Figure 8.3-4z. The ELVS station service transformers reduce the voltage from 4.16 kV to the ELVS nominal bus voltage of 480 V, which is distributed by the ELVS to the:

• highly reliable DC power system (EDSS) from BDG-backed motor control centers (MCCs) and circuits.

• normal DC power system (EDNS).

• AC equipment loads through MCCs, power panels, and 480 V/120 V transformers.

• other plant static loads, including the plant lighting system (PLS).

The onsite AC power systems do not support plant safety-related functions. The EHVS, EMVS, and ELVS are described in Section 8.3.1.1.1. The design configuration of the EHVS and its interfaces are depicted in Figure 8.3-2a and Figure 8.3-2b. The design configuration of the EMVS, and its interfaces with plant loads and the ELVS are depicted in Figure 8.3-3a and Figure 8.3-3b. The design configuration of the ELVS and its interfaces with ELVS loads are depicted in Figure 8.3-4a through Figure 8.3-4z. The ratings of major AC power system equipment are listed in Table 8.3-1.

The BPSS provides backup sources of AC electrical power to the NuScale Power Plant when the normal AC power sources are not available. This condition would occur only if none of the NPMs are operating and a connection to a transmission grid is not available either because it is not provided as part of the site-specific design, or if provided, is lost. The BPSS power generation sources include two BDGs and an AAPS.

The BPSS, including its power generation sources, is described in Section 8.3.1.1.2. The AAPS connections to the EHVS 13.8 kV buses are shown in Figure 8.3-2a and Figure 8.3-2b. The design configuration of the BDG portion of the BPSS and its interfaces with the ELVS are depicted in Figure 8.3-5a and Figure 8.3-5b.

The layout of the onsite AC power system equipment located external to the Turbine Generator Buildings (TGBs) and Reactor Building (RXB) is depicted in Figure 1.2-4.

Equipment location and layout allow access for inspection, operability testing, maintenance, and replacement (if required). Adequate working clearance and means of egress is provided in accordance with National Fire Protection Association 70 (Reference 8.3-3).

Power from the UATs is supplied by cable bus to the EMVS power distribution centers (PDCs). The UATs are located in the plant yard near the TGB and in close proximity to the EHVS. The EMVS 4.16 kV PDCs and switchgear are located in close proximity to the UATs as shown in Figure 1.2-4.

2 8.3-2 Revision 4

(CRB), TGBs, Radioactive Waste Building (RWB), and in pre-fabricated PDCs near the loads they serve. The SSTs are located in PDCs near the MCCs and large motors or static loads they serve.

1.1.1 Normal Power Distribution Systems Onsite AC electrical power is normally distributed by the EHVS, the EMVS, and the ELVS. These power distribution systems are described in the following subsections.

13.8kV and Switchyard System The nonsafety-related EHVS provides electrical connections from the turbine generators, the switchyard, and the AAPS to the onsite AC power electrical distribution system and to the offsite power system.

The design configuration of the EHVS and its interfaces with the onsite AC power distribution system are depicted in Figure 8.3-2a and Figure 8.3-2b. The EHVS includes the first intertie (motor-operated disconnect switch) on the high side of the MPTs, the MPT supply breakers, and the 13.8 kV switchgear, breakers, and buses. The EHVS terminates at the high-side terminals of the UATs, which is the interface between the EHVS and the EMVS.

During normal plant operation, each turbine generator (up to 12 per plant site) supplies power to the 13.8 kV generator buses (see Figure 8.3-2a and Figure 8.3-2b) through its own dedicated generator circuit breaker. The offsite power system is connected to the generator buses through the switchyard, MPTs, and grid breakers. The onsite AC power distribution system is connected to the generator buses through the UATs. The power generated by the turbine generators is provided to the plant electrical loads through the UATs and to the offsite power system through the MPTs. Therefore, with at least one NPM operating and generating electrical power, the operating turbine generator provides power to the plant and other connected loads. The ratings of the main generators, generator circuit breakers, and the MPTs are provided in Table 8.3-1. The EHVS circuit breakers are rated and constructed to meet the requirements of IEEE Standard C37.06 (Reference 8.3-23). The EHVS generator circuit breakers are rated and constructed to meet the required capabilities of Institute of Electrical and Electronics Engineers (IEEE) Standard C37.013 (Reference 8.3-24). If the NPMs are not operating, power to the plant loads is supplied from either the offsite power system or the BPSS.

The EDNS provides control power to the 13.8 kV EHVS. See Section 8.3.2 for information related to the EDNS.

As depicted in Figure 8.3-2a and Figure 8.3-2b, up to eight MPTs, and associated generator buses are provided for the NuScale Power Plant. The generator buses and their associated MPTs are equally divided between the north and south TGBs with up to four generator buses and their associated MPTs serving each TGB. The MPTs are three-phase transformers designed for outdoor use. Each MPT and its 2 8.3-3 Revision 4

The design of the MPTs and associated cabling and switchgear allows one or more main generators, an MPT, a generator bus, or a switchgear to be removed from service for maintenance or refueling without loss of electrical power to the external loads or plant loads. This configuration also allows electrical power to be supplied to plant loads from a single turbine generator with the other turbine generators out of service.

Island mode is a capability that allows operation of the NPMs without a connection to a transmission grid that could provide an offsite AC power supply. In island mode, the plant turbine generators independently provide power to onsite AC loads. Island mode is a nonsafety and non-risk significant design feature that is not credited to meet regulatory or safety-related criteria.

For a NuScale Power Plant that is connected only to a micro-grid or a dedicated service load, island mode represents a normal operating condition with one or more turbine generators providing power to the onsite and offsite AC loads. For a NuScale Power Plant that is normally connected to an offsite power supply via a transmission grid, island mode represents a temporary operating condition until the grid operability is restored.

For the plants with a transmission grid connection, island mode also includes an automatic control function to transition to island mode and maintain power to onsite AC loads in the event the grid is lost or becomes unstable. This automatic function separates the plant from the grid, maintains the operating reactors critical, and maintains uninterrupted power to the onsite AC loads. The service unit is a pre-selected unit (a single NPM and turbine generator combination) that provides power to the plant house loads and sets the AC system frequency and voltage upon automatic transfer to island mode. All units in the plant have the capability to be designated as the service unit.

Given a signal that the grid is lost or unstable, the basic response of the island mode control logic is as follows.

• The switchyard breakers that connect the grid to the plant buses are tripped.

• The service unit generator is switched from droop to isochronous control.

• The turbines and generator breakers for the operating non-service units are tripped and steam is diverted to the associated condensers via the bypass.

• The AAPS is automatically started and may be manually placed in parallel for load following with the service unit in accordance with operating procedures.

After island mode is established and the plant is stable, the operators may choose to reduce power or shutdown units depending on grid and unit conditions.

Although the island mode control function is not credited in the safety design basis, it enhances safety by reducing challenges to the safety systems that would respond to an unmitigated grid disturbance, which includes safety systems actuations that result in a reactor trip.

2 8.3-4 Revision 4

The EMVS is classified as nonsafety-related and its primary function is to supply 4.16 kV power to plant loads during normal power module operations, including NPM startup and shutdown. Each EMVS bus is supplied by a UAT connected to an EHVS bus. Each EMVS bus supplies two ELVS load centers. The loads provided by the EMVS include the ELVS station service transformers and the pump motors for the circulating water system, the site cooling water system, and the chilled water system (CHWS). The EMVS does not provide power to safety-related systems or components.

The EMVS includes UATs, 4.16 kV PDCs, power and control cables, associated raceways, and auxiliaries, such as instrumentation and controls (I&C) and protective relays. These components are described in Section 8.3.1.2.1, Section 8.3.1.2.2, and Section 8.3.1.4. Each UAT is a three-phase, oil-insulated transformer with a single set of secondary windings. The UATs are designed for outdoor mounting and are located in the transformer areas as shown on Figure 1.2-4. As shown in Figure 8.3-3a and Figure 8.3-3b, the primary side of each UAT is connected to its respective EHVS 13.8 kV main generator bus. The 4.16 kV secondary side of each UAT is connected by cable bus to its respective EMVS switchgear. Table 8.3-1 provides the design ratings of the UATs and switchgear. The EMVS switchgear locations are shown in Figure 1.2-4. The loss of an EMVS bus can be mitigated by operating loads on another EMVS bus. The EMVS permanent plant nonsafety loads can be supplied during extended unavailability of the normal power supply, e.g.

plant outages, by the BPSS through the EHVS. The BPSS (auxiliary AC power source) interface circuit has sufficient capacity to supply power to maintain shutdown.

Four UATs are provided for the six main generators in the north TGB (which are connected to NPMs 1 through 6), and the remaining four UATs serve the six main generators in the south TGB (which are connected to NPMs 7 through 12).

Operational flexibility is provided by the capability to cross-connect the EMVS buses on the north and south sides. The loss of a UAT or (( voltage regulating transformer (VRT) )) is mitigated by automatically transferring the affected EMVS bus to an adjacent EMVS bus. The design of the EMVS is such that two UATs can supply the load requirements for six NPMs because each UAT has the capacity and capability to supply 50 percent of the power needed for this configuration under conditions of maximum expected concurrent loads.

Each EMVS bus has tie breakers to adjacent buses. Combined with the UAT capacity, one or two UATs on each side can be removed from service for maintenance without loss of electrical power supply capability to external or plant loads. The EMVS is designed to automatically transfer the connected EMVS bus to another EMVS bus for a UAT lockout relay operation or bus undervoltage condition.

The UATs are provided with tap changers to provide voltage regulation and to maintain secondary voltage within the established voltage limits. The voltage limits are derived from the EMVS load requirements for the expected range of voltage variations on the EHVS, and for the anticipated transformer loading conditions up to the maximum transformer rating.

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The nonsafety-related ELVS consists of the onsite electric power distribution circuits that operate at 600 Vac or less, supplying power to low-voltage loads. The ELVS does not include the distribution systems for the plant lighting system (PLS) or the AC power that is provided by inverters in the nonsafety-related EDNS.

However, the ELVS supplies power to the Class 1E module protection system (MPS) inline breakers for the pressurizer heaters. These breakers are included in the scope of the MPS discussed in Section 7.1. The distribution systems for the PLS and EDNS, including the AC power inverted by the EDNS, are described in Sections 9.5.3 and Section 8.3.2.1, respectively.

Figure 8.3-4a through Figure 8.3-4z depict the ELVS design configuration for a 12-NPM plant. The ELVS begins at the high-side terminals of the SSTs and ends at the input terminals of the EDSS and EDNS battery chargers; the input terminals of equipment loads, including motors and packaged equipment; and the primary side of lighting transformers. The ELVS includes the SSTs, 480 V load centers, MCCs, distribution transformers, and distribution panels or switchboards. The ELVS also includes power and control cables and associated raceways, and auxiliaries such as I&C and protective relays. These components are described in Section 8.3.1.2.1, Section 8.3.1.2.2, and Section 8.3.1.4. Table 8.3-1 provides the design ratings of the major ELVS components. The layout of the ELVS power distribution centers in the yard area is shown on Figure 1.2-4, with the remainder of the ELVS equipment being located inside the plant buildings.

As shown in Figure 8.3-4a through Figure 8.3-4z, the ELVS is divided into two divisions, nonsafety-related Division 1 and nonsafety-related Division 2. Each division supplies power to its connected nonsafety-related loads. Electrical power to each SST is provided from the EMVS. To maximize plant availability and operational flexibility, the ELVS is designed so that failure or unavailability of a single SST does not adversely affect NPM operation.

Each NPM is supplied by two double-ended ELVS main-tie-main load centers that have an SST connected to each load center bus through a main breaker. One of the load centers consists of two buses of nonsafety-related Division 1 power and the other load center consists of two buses of nonsafety-related Division 2 power. Each SST and its EMVS power supply feed has the capacity to provide power to both load center buses. Therefore, if the SST for a load center bus fails or is unavailable, continuous system operation is maintained by automatic transfer of the affected bus to the remaining bus by the tie breaker between the two load center buses.

Electrical interlocks are provided to prevent parallel operation of redundant sources feeding the ELVS buses.

1.1.2 Backup Power Supply System The principal function of the nonsafety-related BPSS is to provide electrical power to the NuScale Power Plant when the normal AC power is not available.

Safety-related functions do not rely on AC electrical power from the BPSS. The BPSS includes two redundant BDGs and an AAPS, as well as electrical equipment and circuits used to interconnect the BDGs to the ELVS and the AAPS to the EHVS.

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time delay after the loss of voltage signal eliminates transient or false alarms. The BPSS equipment status and indication are available both locally and in the main control room (MCR). The operator has the capability to manually start the BDGs and the AAPS locally or in the MCR.

The BDGs, the AAPS, and their associated electrical equipment and circuits are described below.

Backup Diesel Generators The primary function of the BDGs is to provide backup electrical power to certain loads in the post-72 hour period following a station blackout event. The BDG loads are listed in Table 8.3-2.

The two redundant onsite BDGs provide backup electrical power to the EDSS, which is the normal source of power for Type B, Type C, and select Type D post-accident monitoring (PAM) instrumentation and MCR emergency lighting.

The BDGs are each sized to accommodate the capacity of the EDSS battery chargers and other selected "non-EDSS" loads which provide electrical power to post-72 hour loads while simultaneously recharging the EDSS batteries. Other systems and equipment loads include select nonsafety-related, non-risk-significant loads that provide asset protection and operational flexibility.

The BDGs provide backup power to the supported loads through the ELVS distribution equipment if the normal sources of AC electrical power are unavailable. See Figure 8.3-4a through Figure 8.3-4z, and Figure 8.3-5a and Figure 8.3-5b for the interfaces between the ELVS and the BDG equipment.

The BDGs and associated equipment are designed to Seismic Category II. The locations of the BDGs are shown on the plant layout drawing provided in Figure 1.2-4. The BDGs are independent and separated from each other to provide assurance that a fire or adverse event in one BDG does not prevent operation of the other BDG.

Each BDG is a stand-alone, skid-based installation which includes the following subsystems:

• diesel engine starting subsystem

• combustion air intake and engine exhaust subsystem

• engine cooling subsystem

• engine lubricating oil subsystem

• engine fuel subsystem (including fuel storage and transfer)

• generator excitation, protective relaying, and I&C subsystems The onsite BDGs are provided with I&C to facilitate manual startup and shutdown, either locally or from the MCR, and for monitoring and control during operation.

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addition, the BDG switchgear is provided with a plug-in connection. The connection facilitates the use of a portable 480V AC generator to provide power in the event of a complete loss of AC power with the BDGs unavailable.

((The BDG switchgear assemblies are located inside the DGBs. This switchgear also provides power to the DGB heating ventilation and air conditioning system.))

The 480 V MCCs are a part of the ELVS and used to power selected loads. The BDG electrical boundary with the ELVS is at the alternate feed terminals of the ELVS MCCs.

Auxiliary Alternating Current Power Source The onsite AAPS is capable of providing power to the onsite AC power system during periods when the normal AC power sources are not available. The nonsafety-related AAPS is provided for operational flexibility and investment protection, and does not provide a nuclear safety function. The AAPS is sufficiently sized to support startup of the first NPM (i.e., black start), and for normal controlled shutdown and cooldown of NPMs in the unlikely event involving a simultaneous loss of the operating main generators and the transmission grid connection (if provided).

The AAPS is connected directly to the EHVS 13.8 kV generator buses through its generator circuit breaker as shown in Figure 8.3-2a and Figure 8.3-2b.

The location, type (e.g., combustion turbine generator), and design of the AAPS is site-specific. The conceptual location of the AAPS is indicated on the plant layout drawing provided in Figure 1.2-4. The AAPS is independent and physically separated from the BDGs to minimize adverse impacts of a potential failure (e.g.,

fuel oil fire) in one source on the other.

Item 8.3-1: A COL applicant that references the NuScale Power Plant design certification will describe the site-specific location, type, and design of the power source to be used as the auxiliary alternating current power system.

1.2 Design Evaluation 1.2.1 Raceway and Cable The raceway system for the onsite AC power system is nonsafety-related, non-Class1E, and consists primarily of cable tray and rigid metal conduit.

Non-metallic conduit may be used when encased in concrete or directly buried.

Independence of Electrical Circuits The onsite AC power system is nonsafety-related and non-Class 1E; therefore, the electrical system independence guidance of Regulatory Guide (RG) 1.75, Rev. 3 and IEEE Standard 384-1992 (Reference 8.3-16) are not applicable with respect to 2 8.3-8 Revision 4

Standard 384-1992 are applied to the onsite AC power system to ensure adequate independence is maintained between the nonsafety-related equipment and circuits of the onsite AC power system and the Class 1E I&C equipment and circuits.

The provisions applied to ensure this independence, including the means used to distinguish between Class 1E components (i.e., cables, raceways, and terminal equipment) and onsite power system components, are described in Section 7.1.

Cable Derating and Cable Tray Fill The power cable ampacities are in accordance with National Electrical Manufacturers Association WC 51 (Reference 8.3-2), and the National Electric Code (Reference 8.3-3). Power cable derating is based on the type of installation, the conductor and ambient temperature, the number of cables in a raceway, and the grouping of the raceways. Additional derating of the cables is applied to cables that pass through a fire barrier. The method of calculating these derating factors is determined from Reference 8.3-2.

For circuits routed partially in conduit and partially in cable trays or underground ducts, the cable size is based on the ampacity in the portion of the circuit with the lowest current carrying capacity.

Cable tray design is based on random cable fill percentage of usable tray depth per Reference 8.3-3. Conduit fill design is in accordance with the National Electrical Code as well.

Raceway and Cable Routing Onsite AC power system circuits (other than the BPSS) are routed from the UATs in the transformer areas to plant buildings and outside areas requiring electrical power. The BDG circuits are routed from the BDGs to the BDG switchgear. The BDG switchgear is connected to two ELVS distribution switchgears. The ELVS distribution switchgear is connected to the 480 V MCCs for associated NPMs. The ELVS distribution switchgear is strategically located within the vicinity of the connected loads to limit routing of the feeder cables and to maintain separation between the circuits from the two BDGs.

Onsite AC power system circuits do not penetrate the CNVs. Section 7.1 describes the safety-related I&C circuits that penetrate the containment.

Cable trays that are arranged in a vertical array are arranged physically from top to bottom, in accordance with the function and voltage class of the cables as follows:

• medium voltage power (4.16 kV)

• low voltage power (480 Vac, 120 Vac, 125 Vdc, 250 Vdc)

• signal and control power (120 Vac, 125 Vdc, 250 Vdc, if used)

• instrumentation (analog and digital) 2 8.3-9 Revision 4

The non-Class1E AC power system raceway is routed to the extent practicable to avoid proximity to safety-related equipment, pipe, I&C raceways, or ductwork such that the potential for seismic interaction does not exist. Where this cannot be avoided, raceways and supports are designed as Seismic Category II to avoid adverse structural interaction or failure of Seismic Category I components. The nonsafety-related electrical raceway design is normally Seismic Category III.

1.2.2 Circuit Protection and Coordination This section provides a description of the circuit protection and coordination provisions used in the design of the onsite AC power systems.

Protective relay schemes and direct-acting trip devices on circuit breakers

• provide safety of personnel.

• minimize damage to transformers, switchgear, cables, motors, and auxiliary loads.

• minimize system disturbances.

• isolate faulted equipment and circuits from unfaulted equipment and circuits.

• maintain (selected) continuity of the power supply.

• provide alarms.

Electric circuit protection device setpoints are selected and coordinated such that the protective device nearest the fault operates to isolate a fault. Consequently, electrical faults are localized to the smallest possible area without causing interruption or damage to other areas of the system. Protective devices are selected and sized, and setpoints are determined to maximize personnel safety and equipment operation, serviceability, and protection. Coordination studies are conducted in accordance with IEEE Standard 242-2001 (Reference 8.3-4) to verify the protection feature coordination capability to limit the loss of equipment due to postulated fault conditions.

Major features of protection systems employed in the design of the onsite AC power system are described in the following subsections.

13.8 kV and Switchyard System Circuit Protection and Coordination The EHVS protection scheme consists of primary and secondary protection. Each generator and MPT is protected by two multi-function relays each having two independent means of detection and initiation. Each 13.8 kV bus and each switchyard bus section has two differential protection relays. The EHVS protection scheme also contains a design feature such that loss of control power to the protective device does not prevent protection capability.

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guideline IEEE Standard 242-2001 (Reference 8.3-4).

Medium Voltage Alternating Current Electrical Distribution System Circuit Protection and Coordination The EMVS buses are provided with two levels of loss-of-voltage protection. The higher level initiates an auto transfer of the EMVS bus to the selected adjacent bus.

The lower level provides motor protection. The protection schemes use coincidental logic, (e.g. two out of three phases) to avoid spurious actuations of the protective functions.

The protection scheme for the UATs consists of primary and backup protective devices.

Low Voltage Alternating Current Electrical Distribution System Circuit Protection and Coordination The ELVS protective relaying design ensures proper relay coordination for fault clearing and to prevent spurious breaker trips. Fault clearing is provided at the nearest upstream circuit breaker. Zone-overlapping relaying with primary and backup protective functions is incorporated into the ELVS protection scheme using solid-state relays for personnel and equipment protection. The protective schemes prevent spurious trips by discriminating between actual faults and overload conditions. The trip setting of ELVS circuit breakers and selection of fuse ratings is coordinated based on coordination studies performed in accordance with IEEE Standard 242-2001, (Reference 8.3-4).

The ELVS power system operating parameters are monitored throughout their anticipated normal and abnormal operating ranges. Both manual and automatic functions are provided to permit main-tie-main switching between ELVS buses to maintain a suitable power source for the distribution system, and to disconnect loads upon the failure or unavailability of both normal and alternate power sources.

Backup Power Supply System Circuit Protection The BDG protection scheme provides metering functions and indication locally and in the MCR. The AAPS power is routed through the EHVS, the EMVS and the ELVS circuits and equipment. Protection and coordination for those systems is discussed above.

1.2.3 Electrical Heat Tracing The electric heat tracing system is nonsafety-related and provides electrical heating where temperature above ambient is required for system operation and freeze protection.

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1.2.4 Grounding and Lightning Protection The electrical grounding and lightning protection system (GLPS) is designed in accordance with the following standards that are endorsed by RG 1.204.

• IEEE Standard 665-1995 (Reference 8.3-7)

• IEEE Standard C62.23-1995 (Reference 8.3-9)

• IEEE Standard 666-1991 (Reference 8.3-5)

• IEEE Standard 1050-1996 (Reference 8.3-8)

The electrical GLPS consists of the electrical protective devices for personnel and equipment protection from shock hazards and transient over voltages. The system is composed of the following:

• plant grounding grid

• system grounding

• equipment grounding

• an instrument and computer grounding network

• a lightning protection network for protection of structures, transformers, and equipment Surge suppression and filtering are included in the ELVS, the EMVS, and the EHVS rather than the GLPS.

The plant grounding grid consists of buried, interconnected, bare copper conductors and ground rods forming a plant ground grid matrix. The grid maintains a uniform ground potential and limits the step-and-touch potentials to safe values under fault conditions. The plant grounding grid, including conductor sizing, spacing in the matrix pattern, and ground rod use, is designed based on site-specific parameters, including local soil resistance properties and site layout as described in IEEE Standard 80-2013 (Reference 8.3-10).

Item 8.3-3: A COL applicant that references the NuScale Power Plant design certification will describe the design of the site-specific plant grounding grid and lightning protection network.

The neutral points of the main generators, MPTs, UATs, SSTs, BDGs, and AAPS are connected to the plant grounding grid. The MPTs are solidly grounded on the primary side of the transformer. The UAT secondary winding neutrals are low-resistance grounded through a neutral grounding resistor. The secondary winding neutrals of the SSTs are high-resistance grounded through a neutral grounding resistor. The neutrals of the turbine generators, BDGs, and AAPS are connected to ground in accordance with vendor requirements.

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assemblies, load centers, MCCs, switchboards, panelboards, and control cabinets to the plant grounding grid.

The instrument and computer grounding network provides plant I&C and computer grounding through separate radial grounding systems consisting of isolated instrumentation ground buses and insulated cables.

Lightning protection for the plant is accomplished by providing a low-impedance path for the lightning stroke to discharge to the earth directly. The lightning protection network consists of air terminals, interconnecting cables, and downcomers connected directly to the plant ground. The lightning arresters are connected directly to ground in order to provide a low-impedance path to ground for the surges caused or induced by lightning. Surge arrestors are provided to protect the MPTs, UATs, and EMVS switchgear from lightning surges to avoid fire or damage to the plant from a lightning strike.

1.2.5 Containment Electrical Penetration Assemblies The NuScale design of electrical penetration assemblies (EPAs) conforms to GDC 50. This section describes the electrical design requirements for EPAs as they relate to compliance with GDC 50. The NuScale containment system, including EPAs, can accommodate the calculated pressure and temperature conditions resulting from a LOCA in accordance with GDC 50 as described in Section 6.2.1. The mechanical design requirements for EPAs are described in Section 3.8.2. The environmental qualification requirements for EPAs are described in Section 3.11.2.

The electrical penetration assemblies are designed in accordance with IEEE Standard 317-1983 (Reference 8.3-25) as endorsed by RG 1.63. The EPAs are provided with external circuit protection per Section 5.4 of IEEE Standard 741-1997 (Reference 8.3-26), which is consistent with the 1986 version endorsed by RG 1.63, and per IEEE Standard 242-2001 (Reference 8.3-4) with the following clarifications.

Self-limiting circuits are those circuits that use EPAs, are not equipped with protection devices, and are supported by analysis that has determined that the maximum fault current in these circuits would not damage the penetration if that current was available indefinitely. For these circuits, consideration of special protection devices is not required. For circuits that are not self-limiting, primary and backup protective devices are provided. EPAs are designed to withstand the maximum available fault and overload currents for the time sufficient for operation of backup devices in case of failure of the primary protection devices.

Circuits contained in the following EPAs support safety-related functions, and consistent with IEEE 308-2001 (Reference 8.3-15) are classified as Class 1E: CNV 17, 18, 19, and 20. The circuits in the remaining EPAs do not support safety-related functions and are classified as non-Class 1E. Protection devices for non-Class 1E circuits using EPAs are not required to be treated as Class 1E.

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Revision 3.

1.2.6 Electrical Equipment Subject to Wetting or Submergence The onsite AC power system circuits are not routed through the CNVs. Therefore, they are not subjected to wetting or submergence when the CNV contains water or steam.

None of the AC power system power cables provide power to equipment that performs a safety-related function. A loss of, or degraded condition on, the AC power system, including those due to environmental conditions, such as wetted conditions or submergence, would not adversely affect the functionality of accident mitigation systems or nuclear safety.

1.2.7 Onsite Alternating Current Power System Conformance with Regulatory Framework This section describes the extent to which the design of the main onsite AC power system, including the EHVS, the EMVS, the ELVS, and the BPSS, conforms to Nuclear Regulatory Commission (NRC) requirements and guidance. As such, the information in this section provides clarification for the associated entries in Table 8.1-1 of Section 8.1.

The applicability of NRC requirements and guidance to DC power systems, including the EDNS and its AC electrical equipment powered by inverters, and the EDSS, is described in Section 8.3.2.2.2.

General Design Criterion 2 The onsite AC power system does not contain SSC that are required to function in the event of natural phenomena. Nonsafety-related SSC with the potential for adverse seismic interaction with Seismic Category I SSC are designed to Seismic Category II requirements so that their failure does not affect the ability of a safety-related SSC to perform its intended function.

General Design Criterion 4 The onsite AC power system does not contain SSC required to function under adverse environmental conditions associated with postulated accidents, including a loss-of-coolant accident. The nonsafety-related AC power system SSC are designed to operate within the environmental conditions associated with normal operation, maintenance, and testing. Failure of the onsite AC power system components does not introduce adverse environmental conditions that would affect the ability of safety-related SSC to perform their intended functions.

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The onsite AC power systems are shared between NPMs as shown on Figure 8.3-2a, Figure 8.3-2b, Figure 8.3-3a, Figure 8.3-3b, Figure 8.3-4a through Figure 8.3-4z, Figure 8.3-5a, and Figure 8.3-5b. Failures affecting the onsite AC power systems do not affect the ability to achieve and maintain NPM safety functions, including a design basis event (DBE) in one NPM.

General Design Criterion 17 The NuScale design supports an exemption from GDC 17. The NuScale Power Plant is designed with passive safety-related systems for safe shutdown, core and spent fuel assembly cooling, containment isolation and integrity, and reactor coolant pressure boundary (RCPB) integrity. Electrical power is not relied upon to meet specified acceptable fuel design limits nor to protect the RCPB as a result of anticipated operational occurrences or postulated accidents.

Although not relied on to ensure plant safety-related functions are achieved, the onsite electric AC power systems are designed with reliability considerations, including independence, redundancy, and testability. The onsite AC electrical systems are classified as non-Class1E.

General Design Criterion 18 As described above, the NuScale design supports an exemption from the GDC 17 requirements. Accordingly, the NuScale design supports an exemption from the GDC 18 inspection and testing requirements.

General Design Criterion 33 The NuScale design supports an exemption from GDC 33, as described in Section 3.1.4.

General Design Criteria 34, 35, 38, 41, and 44 The plant design complies with a set of principal design criteria in lieu of these GDC, as described in Section 3.1.4. The principal design criteria do not include requirements for electric power systems.

General Design Criterion 50 The electrical design requirements for electrical penetration assemblies (EPAs) comply with GDC 50 as described in Section 8.3.1.2.5.

10 CFR 50.34(f)(2)(xiii)

As described in Section 8.1.4.3, the NuScale design supports an exemption from the 10 CFR 50.34(f)(2)(xiii) (Three Mile Island (TMI) Item II.E.3.1) requirements.

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As described in Section 8.1.4.3, the NuScale Power Plant design does not include pressurizer relief valves or pressurizer relief block valves. Therefore, 10 CFR 50.34(f)(2)(xx) (TMI Item II.G.1) requirements to provide emergency power sources and qualified motive and control power connections for such valves are not technically relevant to the NuScale Power Plant design. The NuScale design supports an exemption from the portions of the rule that require vital power buses for pressurizer level indicators.

10 CFR 50.55a(h)

The onsite electrical AC power system equipment is not a protection system and does not perform safety-related functions. Therefore, the system is not required to conform to 10 CFR 50.55a(h) and IEEE Standard 603-1991 (Reference 8.3-19) endorsed by RG 1.153, Rev. 1. The conformance of the design of I&C equipment and circuits, such as Class 1E pressurizer heater circuit breakers that are not within the scope of the on-site electrical systems, to 10 CFR 50.55a(h) is shown in Table 7.0-1.

10 CFR 50.63 The NuScale Power Plant conformance with 10 CFR 50.63 is described in Section 8.4.

10 CFR 50.65(a)(4)

The development and implementation of the maintenance rule (10 CFR 50.65) program, including the identification of SSC that require assessment per 10 CFR 50.65(a)(4), is stated in Section 17.6.

10 CFR 52.47(b)(1)

See section 14.3 for the methodology related to developing the Inspections, Tests, Analyses, and Acceptance Criteria for AC systems.

Regulatory Guide 1.6 (March 1971)

The scope of RG 1.6 is limited to independence of standby power sources and Class 1E distribution systems. Because the onsite electrical AC power systems do not contain Class 1E distribution systems, this RG is not applicable to the AC electrical system design.

Regulatory Guide 1.32, Rev. 3 The NuScale Power Plant design uses passive safety systems that do not require AC electric power to fulfill safety-related functions and the onsite electric AC power systems are nonsafety-related. Therefore, RG 1.32 is not applicable.

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The onsite electric AC power systems do not perform safety-related functions.

Therefore, application of the single-failure criterion to these systems is not required.

Regulatory Guide 1.63, Rev. 3 The electrical design requirements for electrical penetration assemblies (EPAs) satisfy RG 1.63 as described in Section 8.3.1.2.5.

Regulatory Guide 1.68, Rev. 4 Regulatory Guide 1.68 is implemented using a graded approach to testing in order to provide reasonable assurance, considering the importance to safety of the item, that the item performs satisfactorily while, at the same time, accomplishing the testing in a cost-effective manner. Preoperational testing of the onsite AC electrical system is performed as part of the initial test program described in Section 14.2.12.

Regulatory Guide 1.75, Rev. 3 The onsite electric AC power systems do not perform safety-related functions and do not contain Class 1E circuits. However, the RG 1.75 requirements are implemented for these nonsafety AC power system circuits by requiring physical separation from safety circuits throughout the plant. This criterion forms the basis for the design, routing, and modeling of electrical cable trays and raceways.

Regulatory Guide 1.81, Rev. 1 With respect to the sharing of AC electrical systems, RG 1.81 applies to multi-unit plants that require emergency AC power for safe shutdown supplied by diesel generators. The NuScale Power Plant does not require electrical power (or operator action) to ensure safe shutdown for a DBE, assuming a single failure and loss of offsite power, for a minimum of 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />. Thus, consistent with the Commission policy for passive advanced light water reactor designs, onsite emergency (Class1E) diesel generators are not used in the NuScale Power Plant. Based on the above, RG 1.81 is not relevant to the NuScale AC power systems design.

Portions of the onsite AC power system, including the non-Class1E BDGs, are shared by the NPMs. Sharing of this equipment by the NPMs does not impair the ability to achieve and maintain safety-related NPM functions, including the assumption that a DBE occurs in one NPM. Conformance to the sharing provisions of GDC 5 is described above.

Regulatory Guide 1.106, Rev. 2 The NuScale Power Plant design does not include safety-related, motor-operated valves and, therefore, RG 1.106 is not applicable.

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Periodic testing of onsite AC power system equipment is described in Section 8.3.1.3.

Regulatory Guide 1.153, Rev. 1 Regulatory Guide 1.153 provides guidance that has been codified in 10 CFR 50.55a(h), requiring that safety systems meet the requirements for safety systems in IEEE Standard 603-1991 (including the correction sheet dated January 30,1995). As described in the discussion of conformance to 10 CFR 50.55a(h) above, onsite electrical AC power system equipment is not required to conform to 10 CFR 50.55a(h) and IEEE Standard 603-1991.

Regulatory Guide 1.155 (August 1998)

Regulatory Guide 1.155 provides guidance for implementing the station blackout requirements of 10 CFR 50.63. The extent to which the NuScale plant conforms with RG 1.155 is detailed in Section 8.4.

Regulatory Guide 1.160, Rev. 3 Regulatory Guide 1.160 provides guidance for monitoring the effectiveness of maintenance at nuclear power plants. The development and implementation of the maintenance rule (10 CFR 50.65) program, including the identification of SSC that require assessment per 10 CFR 50.65(a)(4), is stated in Section 17.6.

Regulatory Guide 1.204 (November 2005)

Details demonstrating conformance with RG 1.204 and the IEEE standards it endorses are provided in Section 8.3.1.2.4.

Regulatory Guide 1.218 (April 2012)

Regulatory Guide 1.218 provides guidance for monitoring the condition of cables that have been determined to fall within the scope of the maintenance rule (10 CFR 50.65). The development and implementation of the maintenance rule program, including the identification of SSC that require assessment per 10 CFR 50.65(a)(4), is stated in Section 17.6.

Branch Technical Position 8-2, Rev. 3 The intent of Branch Technical Position (BTP) 8-2 is to ensure that the provision of GDC 17 is met with respect to minimizing the probability of concurrent loss of electrical power sources. This guidance precludes the use of onsite standby AC power sources for purposes other than supplying standby power when needed.

With the NuScale Power Plant non-reliance on AC power for the performance of safety-related functions, the concurrent loss of onsite and offsite AC power sources does not adversely affect plant safety. Notwithstanding this conclusion, for operational, commercial, and plant investment protection purposes, the BDGs are 2 8.3-18 Revision 4

load testing.

As described in Section 8.3.1.1, there are certain operating conditions during which the AAPS may be interconnected with other AC power sources (e.g., one or more NPM turbine generators or offsite power sources, if available). The NuScale design does not rely on AC power sources for the performance of safety-related functions, and the guidance of BTP 8-2 need not be applied to the AAPS.

Branch Technical Position 8-4, Rev. 3 Branch Technical Position 8-4 establishes the acceptability of disconnecting power to electrical components of a fluid system as one means of designing against a single failure that might cause an undesirable component action. Removal of electric power from safety-related valves is not used in the NuScale Power Plant design as a means of satisfying the single failure criterion. Therefore, this BTP is not applicable to the NuScale design.

Branch Technical Position 8-6, Rev. 3 The undervoltage provisions contained in BTP 8-6 are not relevant to the NuScale Power Plant design because a loss of voltage or a degraded voltage condition on the offsite power system does not adversely affect the performance of plant safety-related functions.

Branch Technical Position 8-9, Rev. 0 The criteria specified in BTP 8-9 relevant to passive plant designs are considered as described in Section 8.2.

SECY 94-084 and SECY 95-132 FSAR Section 17.4.3 describes the NuScale methodology to establish risk significance of SSC. The NuScale process for evaluating SSC against the RTNSS criteria is described in FSAR Section 19.3. This process did not identify safety-related or risk-significant loads for the onsite AC power systems.

The lack of safety-related and risk-significant AC loads and the 72-hour SBO coping capability of the passive NuScale design as described in Section 8.4 obviate the need for an alternate AC power source or a safety-related emergency diesel generator, consistent with SECY 94-084 Parts F and G, which were confirmed in SECY 95-132.

1.2.8 Electrical Power System Calculations and Distribution System Studies for Alternating Current Systems Load-flow studies, short-circuit studies, and motor-starting studies for the AC power system are performed using the Electrical Transient Analyzer Program (ETAP) (Reference 8.3-11).

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Load-flow studies are performed to evaluate whether an acceptable voltage range is maintained at equipment terminals under worst case loading conditions. Voltage drop at equipment terminals is also calculated for the largest motor starting condition. The studies confirm that terminal voltage of equipment meets the acceptable voltage ranges.

Short-Circuit Studies Analyses are performed to evaluate worst-case, bolted, three-phase short-circuit fault currents in the onsite AC power system. The analyses are performed to evaluate acceptable ratings for equipment, such as circuit breakers and switchgear bus work.

The short-circuit current results are compared with and must be less than the acceptance criteria (including at least five percent margin), which are the applicable circuit breaker interrupting and close and latch ratings and maximum bus bracing current capabilities. Table 8.3-1 provides nominal equipment ratings for the AC power system.

Containment electrical penetration assembly overload and short-circuit over-current protection is described in Section 8.3.1.2.5.

Equipment Sizing Studies Equipment sizing was developed from a load list and subsequently verified using the ETAP load flow, voltage regulation, and short-circuit analysis results. Worst case loading was determined and equipment was selected that enveloped the load requirements. Major AC distribution equipment ratings are listed in Table 8.3-1.

The acceptance criteria for the major electrical system components are that the equipment ratings (e.g., continuous and short circuit current, voltage, volt-amp) are not exceeded when load flow, voltage drop, short-circuit, and motor starting analyses are performed for normal and off-normal plant alignments and conditions. In general, electrical system equipment sizing includes an approximate ten percent margin.

Equipment Protection and Coordination Studies The distribution system circuit breakers and fuses are selected to carry design loads, and to interrupt overloads and the maximum fault current available at their point of application. Using this selection process, only the protective device nearest the fault operates to isolate the fault or faulted equipment. This results in the fault being localized to the smallest possible area without causing interruption or damage to other portions of the systems. To the extent practical, upstream devices are sized and setpoints are determined so as to sense the fault, but to not operate before the downstream device. Then, if the downstream device fails to operate, the upstream device operates to clear the fault.

2 8.3-20 Revision 4

Insulation Coordination (Surge and Lightning Protection)

Lightning protection is described in Section 8.3.1.2.4.

Power Quality Limits Electrical isolation of safety-related loads from plant AC electrical systems ensures that variations in voltage, frequency, and waveform (harmonic distortion) in the onsite power system does not degrade the performance of safety-related systems.

1.3 Inspection and Testing As described in Section 8.3.1.2.7, the NuScale design supports an exemption from GDC 18. However, periodic inspection and testing is performed on the AC power system for operational, commercial, and plant investment protection purposes.

Accordingly, the onsite AC power system is designed to permit periodic inspection and testing to assess the operability and functionality of the systems and the condition of their components.

Specifically, the design described in Section 8.3.1.1 allows for removing portions of the AC power system from operation without affecting continued operation of the plant.

Protection devices are capable of being tested, calibrated, and inspected. Additionally, the interfaces between the BPSS and the other portions of the AC power system allow periodic testing of the BDGs and AAPS to verify their capability to start and accept load.

Preoperational tests are conducted to verify proper operation of the AC power system.

These tests are within the scope of the initial test program described in Section 14.2.

1.4 Instrumentation and Controls The onsite AC power systems are provided with monitoring and control capability in the MCR and locally.

The power to I&C systems and protective relays is provided by the plant DC power systems, as described in Section 8.3.2.

2 Direct Current Power Systems 2.1 System Description The onsite DC power systems include the EDSS and the EDNS. These systems are described in the following subsections.

2.1.1 Highly Reliable Direct Current Power System The EDSS is composed of two DC subsystems that provide a continuous, failure-tolerant source of 125 Vdc power to assigned plant loads during normal plant operation and for a specified minimum duty cycle following a loss of AC 2 8.3-21 Revision 4

emergency lighting and PAM information displayed in the MCR. The EDSS-module-specific (EDSS-MS) plant subsystem consists of up to12 separate and independent DC electrical power supply systems, one for each NPM.

The EDSS-MS consists of four power channels and EDSS-C consists of two power divisions. EDSS-MS and EDSS-C are capable of providing uninterrupted power to their loads. EDSS-MS Channels A and D have a specified minimum battery duty cycle of 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, and EDSS-MS Channels B and C have a specified minimum battery duty cycle of 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />. The EDSS-C power divisions have a specified minimum battery duty cycle of 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />. The 24-hour battery duty cycle of EDSS-MS Channels A and D is specified to preclude unnecessary ECCS valve actuation for a minimum of 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> following a postulated loss of AC power, unless a valid ECCS actuation signal is received (see Section 6.3.2 for additional information on ECCS operation). The 72-hour battery duty cycle for EDSS-MS Channels B and C and EDSS-C provides a minimum of 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> of DC electrical power for MCR emergency lighting and certain equipment supporting PAM. These EDSS-MS and EDSS-C systems are not credited to meet the acceptance criteria for accident analyses in Chapter 15.

Figure 8.3-6, Figure 8.3-7a, and Figure 8.3-7b provide the simplified one-line diagrams of the EDSS-C and EDSS-MS systems, respectively, and show the demarcation between the EDSS and the Class 1E I&C equipment served by the EDSS-MS.

The source of electrical supply to the EDSS-C and EDSS-MS battery chargers is the ELVS, through the BDG-backed distribution equipment, described above in Section 8.3.1.1.2.

The EDSS-C serves plant common loads as summarized in Table 8.3-4. There are a total of four 125 Vdc batteries and four battery chargers (two batteries and chargers in Division I and two batteries and chargers in Division II) in the EDSS-C subsystem for a NuScale Power Plant containing 1 to 12 NPMs. Each EDSS-C battery consists of 60 cells, sized for a 72-hour duty cycle to provide power to the plant common 125 Vdc loads.

Each EDSS-C battery charger is designed to supply electrical power to its connected loads while simultaneously recharging its associated battery from the design minimum charge state to 95 percent of full charge within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

When a battery or charger is not functional or is taken out of service for maintenance, the redundant battery or charger is capable of serving the full load of the affected EDSS-C division.

During normal plant operations, the 480 Vac power source to the EDSS-C battery chargers is the ELVS. The chargers normally supply power to their connected loads in addition to maintaining the batteries fully charged. Therefore, upon a loss of power to all battery chargers, both the Division I and Division II EDSS-C batteries 2 8.3-22 Revision 4

The EDSS-MS for an NPM provides electrical power for the MPS, other loads associated with that NPM, and the electrical loads shown in Table 8.3-5. There are eight 125 Vdc batteries and eight 125 Vdc battery chargers in each EDSS-MS subsystem (two batteries and chargers in each of redundant Channels A and D, and redundant Channels B and C). Each battery consists of 60 cells connected in series to produce 125 Vdc.

During normal operations, the 480 Vac ELVS provides power to the EDSS-MS battery chargers from the BDG-backed ELVS motor control centers. The chargers normally supply power to plant loads in addition to maintaining the batteries fully charged. Upon a loss of power to all battery chargers, the bus and connected loads remain energized directly from the parallel connection with the batteries. Either the primary or redundant standby batteries are capable of providing the necessary power to the loads. The Channel A and Channel D EDSS-MS batteries have sufficient capacity to supply assigned plant loads for 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, while the Channel B and Channel C EDSS-MS batteries have sufficient capacity to supply assigned plant loads for 24 or 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> (as indicated in Table 8.3-5).

The BDGs provide additional capability to preserve battery capacity during the time when normal AC power to the battery chargers is not available by supplying 480 Vac input power to the battery chargers to supply the connected loads and recharge the batteries.

The EDSS is a non-Class 1E power system and is not risk-significant. Augmented design, qualification, and quality assurance (QA) provisions are applied to the EDSS as described in Reference 8.3-1. Table 8.3-10 provides a cross reference of the FSAR sections that demonstrate compliance with the augmented provisions. The EDSS conforms to the design, manufacture, installation, testing, and surveillance provisions of IEEE Standard 308 (Reference 8.3-15) and RG 1.32 as described in the safety classification section of Reference 8.3-1. Consistent with the augmented provisions, the EDSS is designed to provide independent and redundant power to certain load groups arranged by channel (EDSS-MS) or division (EDSS-C). The EDSS design also includes augmented provisions for single and common-cause failures and conforms to IEEE-308 (Reference 8.3-15) and IEEE-379 (Reference 8.3-20) to the extent described in Reference 8.3-1.

An evaluation of EDSS component failures is provided in Table 8.3-7. The evaluation conservatively assumed that each component single failure occurs concurrently with the unavailability of the redundant EDSS channel (EDSS-MS) or EDSS Division (EDSS-C). The results show that even with this conservative assumption, failures do not prevent safety-related functions from being achieved and maintained. Additionally, under normal operating conditions wherein all EDSS channels and divisions are available, a single failure does not result in inadvertent actuation of safety-related functions. An evaluation of the EDSS reliability was performed using the methodology described in Condition of Applicability II.2 of Reference 8.3-1. Using the generic failure probabilities from Section 19.1.4.1.1.5, the EDSS supports the mission requirements with high reliability.

2 8.3-23 Revision 4

the rest of the subsystem for testing. Local and remote indications in the control room ensure the ability for continuously monitoring the batteries, battery chargers, and DC buses during test conditions.

Battery monitors provide continuous monitoring of EDSS battery performance.

The EDSS provides DC power only to DC loads. Therefore, inverters are not required or included in the EDSS design.

The EDSS operates ungrounded. Therefore, there are no connections to ground from either the positive or negative legs of the EDSS batteries or chargers. An ungrounded DC system ensures system reliability and availability in the event one of the system legs becomes grounded. The EDSS includes ground fault detection devices and relays consistent with the recommendations of IEEE Standard 946-2004 (Reference 8.3-13).

The EDSS does not contain safety-related cables.

Physical separation is achieved by installing equipment in different rooms that are separated by 3-hour fire barriers. The EDSS-MS Division I cables (Channels A and C) and raceways are routed separately from EDSS-MS Division II cables (Channels B and D) and raceways. Similarly EDSS-C Division I cables and raceways are routed separately from EDSS-C Division II cables and raceways. Although EDSS electrical power is not required to achieve a safe shutdown, this separation ensures that equipment in one fire area rendered inoperable by fire, smoke, hot gases, or fire suppressant, does not affect the availability of the redundant equipment located in another fire area. The fire protection features and analyses are described in Section 9.5.1.

The EDSS-MS batteries (A, B, C, D) and EDSS transfer switches are located in separate rooms on the 75-foot elevation of the RXB. The EDSS-MS switchgear rooms are located on the 86-foot elevation (immediately above the batteries) and house the EDSS switchgear assemblies, battery chargers, and interconnecting system cabling.

The EDSS-C batteries (Division I, Division II) are located on the 50-foot elevation of the CRB. The EDSS-C switchgear rooms are also located on the 50-foot elevation (immediately adjacent) and contain EDSS-C switchgear assemblies, transfer switches, battery chargers, and interconnecting system cabling.

The location of the chargers and switchgear assemblies associated with each battery are located as close as practical to the battery to minimize voltage drops from the battery to the load under high discharge currents from the battery.

See Table 8.3-3 for EDSS equipment locations. The EDSS equipment rooms are separated by 3-hour fire barriers and interconnecting system cabling is routed such that a complete loss of equipment in one fire area does not challenge the EDSS-MS 2 8.3-24 Revision 4

The EDSS-MS equipment is shown on Figure 8.3-7a and Figure 8.3-7b.

All EDSS equipment is designed to Seismic Category I standards as discussed in Section 3.7 and Section 3.10. The EDSS design includes augmented provisions for seismic qualification. The codes and standards that implement these provisions are described in Reference 8.3-1.

The design of the EDSS includes augmented provisions for component identification and access control. The codes and standards that are used to implement these provisions are described in Reference 8.3-1.

Controls over the reliability and availability of the EDSS-MS power circuitry and supply will be included in the owner-controlled requirement manual described in COL Item 16.1-2.

Highly Reliable Direct Current Power System Batteries The EDSS includes augmented design provisions for batteries. The codes and standards that are used to implement these provisions are described in Reference 8.3-1. Each EDSS battery is composed of 60 valve-regulated lead-acid (VRLA) type cells connected in series to generate 125 Vdc. The VRLA battery cells are sealed, with the exception of a valve that opens to the atmosphere when the internal pressure in the cell exceeds atmospheric pressure by a preselected amount. The VRLA cells provide a means for recombining internally generated oxygen and suppressing hydrogen gas evolution to limit water consumption. The batteries are sized in accordance with IEEE Standard 485-1997 (Reference 8.3-12),

as endorsed by RG 1.212 November 2008. Table 8.3-3 provides a listing of the EDSS major components and their ratings.

Each battery in EDSS-MS Channel A (Division I) and Channel D (Division II) is sized for a 24-hour duty cycle. Each battery is rated 542 ampere-hours for a 24-hour discharge to a final voltage of 105 Vdc or 1.75 volts per cell.

Each battery in EDSS-MS Channel B (Division II) and Channel C (Division I) is sized for a 72-hour duty cycle. The EDSS-MS channels B and C batteries are rated 1039 ampere-hours for a 72-hour discharge to a final voltage of 105 Vdc or 1.75 volts per cell.

Each battery in EDSS-C Division I and Division II is sized for a 72-hour duty cycle.

These batteries are rated 2303 ampere-hours for a 72-hour discharge to a final voltage of 105 Vdc or 1.75 volts per cell.

The EDSS batteries are designed with margin to allow for future load growth, temperature correction, and battery aging. A conservative design margin factor of 1.50 is applied to account for potential load additions during design development (25 percent) and future load growth during plant operating life (25 percent). The 2 8.3-25 Revision 4

Highly Reliable Direct Current Power System Battery Chargers Each EDSS-C and EDSS-MS battery charger capacity is sufficient to supply power to the connected steady-state loads under maximum loading conditions, while at the same time recharging the associated batteries from the design minimum charge state to 95 percent of full charge within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />. The two battery chargers in each EDSS-C division and in each EDSS-MS channel are normally operated in parallel.

The parallel chargers are linked by a load-sharing circuit, which does not rely on software-based technology. The circuit provides for output balancing and is consistent with IEEE 946-2004 (Reference 8.3-13).

The EDSS battery chargers are sized using the guidance of IEEE Standard 946-2004 (Reference 8.3-13). Input voltage to the EDSS battery chargers is 480 Vac, 3 phase.

The DC output voltage is 125 Vdc. See Table 8.3-3 for EDSS battery charger sizing per subsystem.

The EDSS battery chargers have individual controls to manually select float and equalize modes, and to accurately adjust float and equalize voltages within the range recommended by the battery manufacturer. The EDSS battery rooms are maintained as mild environments. When this type of environment is combined with temperature-compensated battery charger output, the risk of a battery thermal runaway condition is reduced during charging of the VRLA batteries. The parallel connection of the EDSS batteries to the chargers allows for the batteries to automatically assume the loads for a loss of AC power to the chargers. Battery chargers include blocking features in their design to prevent their AC source from becoming a load on the batteries.

2.1.2 Normal Direct Current Power System The EDNS is a non-Class 1E DC power system. The EDNS does not serve safety-related loads, and it does not have safety-related functional requirements during plant startup, normal operation, shutdown, or abnormal operation.

Therefore, the EDNS is classified as nonsafety-related and non-risk-significant.

The EDNS is shared between the NPMs and provides both DC power and AC power (through inverters) to nonsafety-related loads that support functions related to investment protection and power generation (i.e., the loads that are part of the plant permanent nonsafety systems).

The EDNS consists of batteries, battery chargers, inverters, VRTs, AC panelboards, maintenance bypass switches, DC switchboards, fused transfer switch boxes, battery monitors, surge suppression, associated EDNS protective relays, instrumentation, and EDNS cabling and wiring. The EDNS battery chargers are supplied from the ELVS, as shown in Figure 8.3-4a through Figure 8.3-4z, Figure 8.3-8a through Figure 8.3-8f, and Table 8.3-8.

2 8.3-26 Revision 4

below:

• RXB (north and south) - 250 Vdc and 120/208 Vac, 3 phase

• TGBs (North/South) - 250 Vdc and 120/208 Vac, 3 phase

• CRB - 125 Vdc and 120/208 Vac, 1 phase

• RWB - 125 Vdc and 120/208 Vac, 1 phase

• PDCs #1 through #6 (yard location) - 125 Vdc

• PDCs #7 (yard location) - 125 Vdc

• PDCs #8 (yard location) - 125 Vdc Equipment redundancy is provided in the EDNS design to allow offline maintenance without affecting plant operation at 100 percent power. Each EDNS design includes a maintenance and test bypass switch to connect to an alternate circuit for offline maintenance or battery testing through a test terminal connection.

The EDNS operates as an ungrounded DC system. Therefore, there are no connections to ground from either the positive or negative legs of the EDNS batteries or chargers. An ungrounded DC system ensures system reliability and availability in the event one of the system legs becomes grounded.

The EDNS battery chargers are normally supplied from the ELVS, as shown in Figure 8.3-4a through Figure 8.3-4z. In the event of a loss of normal onsite AC power, backup power to the ELVS can be provided by the BPSS. Additionally, spare battery and charger terminal connection points are provided for connection to mobile battery and charging units, if necessary.

Non-Class 1E EDNS equipment supports and anchorages for locations in the TGB, the RXB, the RWB, the CRB, and yard PDCs are designed for operating and seismic loads in accordance with NuScale civil and structural design criteria.

Normal Direct Current Power System Batteries Each of the EDNS batteries is sized to supply the most limiting full load requirements continuously for a minimum of 40 minutes without load shedding.

Following a loss of AC electrical power supply to the EDNS battery chargers, the parallel connection of the EDNS batteries to the chargers allows for the batteries to automatically assume the loads. The 40-minute time period is based on the Electric Power Research Institute Utilities Requirement Document (Reference 8.3-14) for backup power supplies to start within 30 minutes plus an additional 10-minute margin.

The number, location, and ratings of the batteries used in the EDNS are described in Table 8.3-8. Each EDNS battery is composed of either 60 or 120 VRLA-type cells connected in series to produce either 125 Vdc or 250 Vdc, respectively.

2 8.3-27 Revision 4

210 Vdc, per IEEE Standard 485-1997 (Reference 8.3-12). The operating voltage range of the 125 Vdc loads is 100 Vdc to 140 Vdc. The operating voltage range of the 250 Vdc loads is 200 Vdc to 280 Vdc.

The EDNS battery design includes margins to allow for future load growth, temperature correction, and battery aging. The future load growth is assumed to be 20 percent. The temperature correction factor used is 1.11, which correlates to 60 degrees F. The battery aging factor used is 1.25.

Normal Direct Current Power System Battery Chargers Select EDNS subsystems contain primary and standby battery chargers, as shown in Figure 8.3-8a through Figure 8.3-8f.

Battery chargers for the EDNS subsystems are sized and capable of supplying 100 percent of the connected normal operating loads while maintaining the battery fully charged. The primary chargers are capable of supplying power to their steady-state loads under maximum loading conditions, while simultaneously recharging their connected batteries from the design minimum charge to 95 percent of full charged condition within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />. The standby chargers (where provided) are also capable of supplying power under the same maximum loading conditions as the primary chargers in the event the primary chargers are not available. Primary and standby chargers in the PDCs are sized with a 20 percent design margin.

Input voltage to the EDNS battery chargers is 480 Vac, three phase provided from the ELVS. The DC output voltage is 125 Vdc or 250 Vdc based on the loads and the system requirements. See Table 8.3-8 for EDNS battery charger sizing per subsystem.

The EDNS battery chargers have individual controls to manually select float and equalize modes, and to accurately adjust float and equalize voltages within the range recommended by the battery manufacturer. The EDNS battery rooms are maintained as mild environments. When this type of environment is combined with temperature-compensated battery charger output, the risk of a battery thermal runaway condition is reduced during charging of the VRLA batteries.

Normal Direct Current Power System Inverters As shown in Table 8.3-8, six of the EDNS subsystems supplying nonsafety AC loads require an inverter. During normal plant operation, the inverters operate continuously loaded. The DC input voltage is either 125 Vdc or 250 Vdc, and the AC output voltage is either 120 Vac single phase or 120/208 Vac three phase based on the load and system requirements. The inverters are sized to carry 100 percent of the connected load. A design margin of 20 percent is included in the inverter sizing calculations to provide for future load growth, 90 percent is used as inverter efficiency, and the inverter power factor is 90 percent. Additionally, the inverter loading level factor of 1.05 ensures that the inverter is adequately sized to carry the 2 8.3-28 Revision 4

per subsystem.

As shown in Figure 8.3-8a through Figure 8.3-8f, each inverter is connected to a DC bus. Upon failure of the battery charger supplying the connected DC bus, the incoming DC power source to the bus supplying the inverter AC loads is automatically transferred from the charger to the EDNS batteries.

The loads requiring AC power from a failed inverter are transferred by a static switch to a VRT to maintain AC power to the connected loads. The static switch design is make-before-break to provide uninterrupted power transfer to the loads.

The switches have three positions: auto, bypass, and inverter, and are rated for 100 percent of the inverter or regulating transformer output, whichever is greater.

Voltage Regulating Transformers As shown in Table 8.3-8, VRTs are included in those subsystems that supply AC loads through the EDNS inverters. The EDNS subsystems requiring a regulating transformer are selected for either single-phase or three-phase application with an input at 480 Vac and output at either 120 Vac single phase or 120/208 Vac three phase based on the load and system requirements. The VRT selection is based on the standard commercially available equipment ratings. See Table 8.3-8 for the EDNS regulating transformer sizing per subsystem.

2.2 Design Evaluation 2.2.1 System Interfaces Highly Reliable DC Power System The ELVS provides AC power to the EDSS battery chargers. AC power to the ELVS is provided by the normal AC power sources (main generators, onsite AC distribution, or offsite transmission grid, if supplied) or by the BDGs.

The EDSS-C and EDSS-MS loads are listed in Table 8.3-4 and Table 8.3-5.

Additionally, the following systems receive highly reliable DC power from the EDSS:

Module Protection System - EDSS-MS channels A, B, C, and D provide electrical power to MPS separation groups A, B, C, and D equipment, respectively. The EDSS-MS Division I (channels A and C) and Division II (channels B and D) provide electrical power to Division I and Division II MPS equipment, respectively. When AC input power to EDSS-MS battery chargers is unavailable, the MPS loads are energized for 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> and PAM loads are energized for 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> as described in Section 7.0.4.1.4. In addition to energizing required loads during the EDSS battery duty cycle, the MPS de-energizes unneeded loads. The MPS logic that de-energizes loads in the event of a loss of AC power to the EDSS-MS battery chargers is shown in Figure 7.1-1ah.

2 8.3-29 Revision 4

input power to the EDSS-C battery chargers is unavailable, the PPS loads required to support PAM are energized for 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> by the EDSS-C batteries. In addition to energizing required loads during the EDSS battery duty cycle, the PPS de-energizes unneeded loads. The PPS logic that de-energizes loads in the event of a loss of AC power to the EDSS-C battery chargers is shown in Figures 7.1-3b and 7.1-3c.

Plant Lighting System - The EDSS-C provides electrical power to MCR emergency lighting. The battery chargers are sized to accommodate this load during normal operation and the batteries are sized to provide power for a minimum of 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> following a loss of normal AC power.

Safety Display and Indication System (SDIS) - The EDSS-C provides electrical power to NPM-specific and common-plant safety displays. The battery chargers are sized to accommodate the display loads during normal operation and the batteries are sized to provide power to these loads for a minimum of 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> following a loss of normal AC power.

Fixed-Area Radiation Monitoring System (RMS) - The EDSS-MS and EDSS-C provide electrical power to the bioshield area and reactor pool area radiation monitors. The battery chargers are sized to accommodate the monitor loads during normal operation and the batteries are sized to provide power to these loads for a minimum of 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> following a loss of normal AC power.

Normal Direct Current Power System The ELVS provides power to the EDNS through the EDNS battery chargers and voltage regulating transformers. Additionally, the following systems receive EDNS power:

• ELVS

• EMVS

• EHVS

• control rod drive system

• feedwater treatment system

• main steam system

• site cooling water system

• gaseous radioactive waste management system

• condensate and feedwater system

• CHWS

• utility water system

• demineralized water system

• nitrogen distribution system 2 8.3-30 Revision 4

• health physics network

• Reactor Building HVAC system (RBVS)

• fire protection system

• fire detection system

• plant control system

• module control system

• PPS for nonsafety loads

• RMS

• in-core instrumentation system

• meteorological and environmental monitoring system

• communication system

• plant-wide video monitoring system

• seismic monitoring system

• EDNS battery room ventilation systems

• post-accident type E variable control and instrumentation loads

• turbine generator system emergency DC lube oil pumps 2.2.2 Onsite Direct Current Power System Conformance with Regulatory Framework This section describes the extent to which the design of the onsite DC power systems, including the EDSS and the EDNS electrical equipment, conforms to NRC requirements and guidance. As such, the information in this section provides clarification for the associated entries in Table 8.1-1 of Section 8.1.

GDC 2 The EDNS is not required to function in the event of natural phenomena events.

The EDNS structures, systems, and components with the potential for adverse seismic interaction with Seismic Category I SSC are designed to Seismic Category II requirements so that their failure does not affect the ability of a safety-related SSC to perform its intended function. The EDSS structures, systems, and components are designed with augmented requirements for protection from the effects of natural phenomena for increased reliability and availability. The EDSS structures, systems, and components are located in the RXB and in areas of the CRB below the 120 ft elevation, which are designed to withstand the effects of and function following natural phenomena such as earthquakes, tornadoes, hurricanes, floods, and externally-generated missiles.

The EDSS structures, systems, and components are further augmented by applying design, qualification, and QA provisions typically applied to Class1E DC power 2 8.3-31 Revision 4

seismic phenomena, Reference 8.3-1 includes augmented seismic design and qualification provisions.

GDC 4 The EDSS design accommodates the effects of environmental conditions by applying augmented provisions for the design, qualification, and QA typically applied to Class1E DC power systems using a graded approach. The graded approach is reflected in the EDSS design, qualification, and QA provisions detailed in Reference 8.3-1. The codes and standards that are used to implement the EDSS environmental qualifications are described in Reference 8.3-1. The physical locations of the EDSS-MSs and EDSS-C within the Seismic Category I RXB and CRB, respectively, provide the EDSS with protection from dynamic effects, including the effects of missiles, pipe whipping, and discharging fluids.

GDC 5 As shown on Figure 8.3-7a and Figure 8.3-7b, the EDSS-MS is not shared between NPMs thus satisfying the intent of RG 1.81, Position C.1. Specifically, portions of the EDSS that supply electrical power to the MPS are not shared. This is achieved by providing each NPM with a dedicated EDSS-MS.

The EDSS includes augmented design provisions for multiple NPMs that prevent sharing of DC power equipment between NPMs that has the potential to result in adverse interactions. The codes and standards that are used to implement these provisions are described in Reference 8.3-1. Sharing of the EDSS-C is shown on Figure 8.3-6. A postulated loss of or power fluctuation on the EDSS-C would not result in adverse interactions between NPMs, and would not impair the performance of safety-related functions necessary to achieve and maintain safe shutdown of the NPMs.

As shown on Figure 8.3-8a through Figure 8.3-8f, the EDNS consists of the EDNSs located throughout the NuScale Power Plant. A failure in these systems does not impair the ability to achieve and maintain NPM safety-related functions.

GDC 17 The NuScale design supports an exemption from GDC 17. The NuScale Power Plant is designed with passive safety-related systems for safe shutdown, core and spent fuel assembly cooling, containment isolation and integrity, and RCPB integrity.

Electrical power is not relied upon to meet specified acceptable fuel design limits nor to protect the RCPB as a result of anticipated operational occurrences or postulated accidents.

Although not relied on to ensure plant safety-related functions are achieved, the onsite electric power systems are designed with reliability considerations, including independence, redundancy, and testability. The onsite electrical systems are classified as non-Class1E.

2 8.3-32 Revision 4

As described above, the NuScale design supports an exemption from the GDC 17 requirements. Accordingly, the NuScale design supports an exemption from the GDC 18 inspection and testing requirements.

GDC 33 The NuScale design supports an exemption from GDC 33, as described in Section 3.1.4.

GDC 34, 35, 38, 41 and 44 The plant design complies with a set of principal design criteria in lieu of these GDC, as described in Section 3.1.4. The principal design criteria do not include requirements for electric power systems.

GDC 50 The electrical design requirements for electrical penetration assemblies (EPAs) comply with GDC 50 as described in Section 8.3.1.2.5.

10 CFR 50.34(f)(2)(xiii)

As described in Section 8.1.4.3, the NuScale design supports an exemption from 10 CFR 50.34(f)(2)(xiii) (TMI Item II.E.3.1).

10 CFR 50.34(f)(2)(xx)

As described in Section 8.1.4.3, the NuScale design supports an exemption from the portions of 10 CFR 50.34(f)(2)(xx) that require vital power buses for pressurizer level indicators. This requirement is not applicable to the DC systems.

10 CFR 50.55a(h)

The onsite electrical DC power system equipment is not a protection system and does not perform safety-related functions. Therefore, the system is not required to conform to 10 CFR 50.55a(h) and IEEE Standard 603-1991 (Reference 8.3-19).

However, the EDSS design is augmented to conform to 10 CFR 50.55a(h) and IEEE Standard 603-1991 to the extent described in Reference 8.3-1. The conformance of the design of I&C equipment and circuits (that are not within the scope of electrical systems) to 10 CFR 50.55a(h) is shown in Table 7.0-1.

10 CFR 50.63 The NuScale Power Plant design conformance with 10 CFR 50.63 is described in Section 8.4.

2 8.3-33 Revision 4

The development and implementation of the maintenance rule (10 CFR 50.65) program, including the identification of SSC that require assessment per 10 CFR 50.65(a)(4), is stated in Section 17.6.

10 CFR 52.47(b)(1)

See section 14.3 for the methodology related to developing the Inspections, Tests, Analyses, and Acceptance Criteria for DC systems.

Regulatory Guide 1.6 (March 1971)

The EDSS design conforms to the guidance for independence of standby power sources and their distribution systems provided in RG 1.6.

Regulatory Guide 1.32, Rev. 3 The EDSS conforms to RG 1.32 and IEEE Standard 308-2001 to the extent described in Reference 8.3-1.

Regulatory Guide 1.41 (March 1973)

The EDSS conforms to RG 1.41 to the extent described in Reference 8.3-1.

Section 14.2 includes preoperational testing to verify the independence of certain EDSS load groups arranged by channel or division. The load groups are associated with EDSS functions that would typically be provided by a Class 1E power supply.

These groups include type B & C post-accident monitoring variables and the associated MCR displays (SDIS), ECCS valves, and MCR emergency lighting.

Regulatory Guide 1.53, Rev. 2 The EDSS conforms to RG 1.53 and IEEE Standard 379-2000 (Reference 8.3-20) to the extent described in Reference 8.3-1.

Regulatory Guide 1.63, Rev. 3 The electrical design requirements for electrical penetration assemblies (EPAs) satisfy RG 1.63 as described in Section 8.3.1.2.5.

Regulatory Guide 1.68, Rev. 4 Initial testing of the EDSS conforms to RG 1.68 with clarifications described in Reference 8.3-1. Per RG 1.68 in that, preoperational testing is implemented using a graded approach to testing in order to provide reasonable assurance, considering the importance to safety of the item, that the item performs satisfactorily while, at the same time, accomplishing the testing in a cost-effective manner. The EDSS preoperational testing is performed as part of the Initial test program described in Section 14.2.12.

2 8.3-34 Revision 4

The EDSS conforms to RG 1.75 and IEEE Standard 384-1992 to the extent described in Reference 8.3-1.

Regulatory Guide 1.81, Rev. 1 The EDSS conforms to RG 1.81 to the extent described in the discussion of conformance to GDC 5 above and Reference 8.3-1.

Regulatory Guide 1.106, Rev. 2 The NuScale Power Plant design does not include safety-related, motor-operated valves and; therefore, RG 1.106 is not applicable.

Regulatory Guide 1.118, Rev. 3 The EDSS conforms to RG 1.118 and IEEE Standard 338-1987 (Reference 8.3-21) to the extent described in Reference 8.3-1. Periodic testing of the EDSS and EDNS equipment is discussed in Section 8.3.2.3.

Regulatory Guide 1.128, Rev. 2 Regulatory Guide 1.128 endorses IEEE Standard 484-2002 (Reference 8.3-22) as an acceptable method of demonstrating compliance with NRC regulations relevant to installation design and installation of vented lead-acid (VLA) batteries. As described in Section 8.3.2.1, the EDSS uses VRLA batteries. Thus, IEEE Standard 1187-2013 (Reference 8.3-17) is applied rather than IEEE Standard 484-2002. However, the regulatory positions of RG 1.128, although directed toward VLA battery installations, are appropriately considered in the installation design of the VRLA batteries, with exceptions and clarifications described in Reference 8.3-1.

Regulatory Guide 1.129, Rev. 3 Regulatory Guide 1.129 endorses IEEE Standard 450-2010 (Reference 8.3-6) as an acceptable method of demonstrating compliance with NRC regulations relevant to maintenance, testing, and replacement of VLA batteries. The EDSS uses VRLA batteries and, thus, applies IEEE Standard 1188-2005 (Reference 8.3-18) with the 2014 amendment rather than IEEE Standard 450-2010. However, the regulatory positions of RG 1.129, although directed toward VLA battery installations, are appropriately considered for the VRLA batteries, with clarification described in Reference 8.3-1.

Regulatory Guide 1.153, Rev. 1 The EDSS conforms to 10 CFR 50.55a(h) and IEEE Standard 603-1991 (and hence RG 1.153) to the extent described in Reference 8.3-1.

2 8.3-35 Revision 4

Regulatory Guide 1.155 provides guidance for implementing the station blackout requirements of 10 CFR 50.63. The extent to which the NuScale Power Plant design conforms to RG 1.155 is described in Section 8.4.

As described in Reference 8.3-1, an augmented quality assurance (QA) program is applied to the EDSS. The program meets the QA provisions of RG 1.155 Appendix A.

Regulatory Guide 1.160, Rev. 3 Regulatory Guide 1.160 provides guidance for monitoring the effectiveness of maintenance at nuclear power plants. The development and implementation of the maintenance rule (10 CFR 50.65) program, including the identification of SSC that require assessment per 10 CFR 50.65(a)(4), is stated in Section 17.6.

Regulatory Guide 1.212 The EDSS and EDNS batteries are sized per IEEE Standard 485-1997 as endorsed by Regulatory Guide 1.212 (November 2008).

Regulatory Guide 1.218 (April 2012)

Regulatory Guide 1.218 provides guidance for monitoring the condition of cables that have been determined to fall within the scope of the maintenance rule (10 CFR 50.65). The development and implementation of the maintenance rule program, including the identification of SSC that require assessment per 10 CFR 50.65(a)(4), is stated in Section 17.6.

Branch Technical Position 8-4, Rev. 3 Branch Technical Position 8-4 establishes the acceptability of disconnecting power to electrical components of a fluid system as one means of designing against a single failure that might cause an undesirable component action. Removal of electric power from safety-related valves is not used in the NuScale Power Plant design as a means of satisfying the single failure criterion. Therefore, this BTP is not applicable to the NuScale design.

SECY 94-084 and SECY 95-132 FSAR Section 17.4.3 describes the NuScale methodology to establish risk significance of SSC. The NuScale process for evaluating SSC against the RTNSS criteria is described in FSAR Section 19.3. This process did not identify safety-related or risk-significant functions for the onsite DC power systems.

2 8.3-36 Revision 4

The following subsections describe the calculations and studies that were developed for the DC power systems. The calculations were performed using the ETAP computer software (Reference 8.3-11).

Load-Flow and Voltage-Regulation Studies, and Undervoltage and Overvoltage Protection The DC load-flow analyses were performed for both the EDNS and EDSS to confirm equipment assumptions and select equipment ratings. The margins for load growth were included in the analyses.

The operating voltage range for the EDSS and EDNS was determined by calculation and accommodates equalize charging the batteries at a specified low temperature.

The operating voltage range for the EDSS-MS and the EDSS-C 125 Vdc batteries is 105 Vdc to 140 Vdc. The operating voltage range for the EDNS 250 Vdc batteries is 200 Vdc to 280 Vdc, and the operating range for the EDNS 125 Vdc batteries is 100 Vdc to 140 Vdc.

Short-Circuit Studies Short-circuit analyses are performed for the EDSS-MS, EDSS-C, and the EDNS DC subsystems. These analyses are performed in accordance with IEEE Standard 946-2004 (Reference 8.3-13) methodology and the available short-circuit currents from each battery and connected charger are determined under a worst case short circuit at the battery terminals.

Equipment Sizing Studies The DC equipment sizing was developed from a load list and was verified using the ETAP load-flow and short-circuit analysis results. Worst-case loading was determined and the power supply equipment was selected that enveloped the loading requirements. The ratings for the major DC equipment are listed in Table 8.3-3 and Table 8.3-8.

The acceptance criteria for the major DC system components are that the equipment ratings are not exceeded when load-flow, voltage-drop, and short-circuit analyses are performed. The equipment sizing includes additional design margin for future load growth.

The EDSS switchgear DC buses are sized based on the calculated loading, which includes an additional margin of 25 percent (1.25 factor) applied to the highest battery charger current during operation in the current-limit mode (i.e.,

150 percent of the battery charger rated full-load current).

The EDNS switchgear DC buses are sized by applying a factor of 120 percent to the highest ampere demand on the battery charger while operating in the current-limit mode and selecting the next higher standard-current value for DC 2 8.3-37 Revision 4

bus ratings per subsystem.

Equipment Protection and Coordination Studies The EDSS includes augmented design provisions for equipment protection. The codes and standards that are used to implement these provisions are described in Reference 8.3-1.

The distribution system circuit breakers and fuses are selected to carry design loads, and to interrupt overloads and the maximum fault current available at their point of application. Using this selection process, only the protective device nearest the fault operates to isolate the fault or faulted equipment. This results in the fault being localized to the smallest possible area without causing interruption or damage to other portions of the systems.

The minimum interrupting rating for the EDSS equipment is greater than the worst-case, short-circuit contribution from the batteries and battery chargers.

The minimum interrupting rating for the EDNS equipment is greater than the worst-case, short-circuit currents from the batteries, battery chargers, and DC motors (as applicable.)

Power Quality Limits The EDSS battery chargers supplied by the ELVS provide electrical isolation between the AC power system and the EDSS. Power quality is a design provision that relies on IEEE Standard 308-2001 (Reference 8.3-15) as endorsed by RG 1.32 and IEEE Standard 741-1997 (Reference 8.3-26) as described in Reference 8.3-1.

The EDSS is isolated from the NMS and MPS by Class 1E isolation devices that are described in Section 7.0.4.1 and Section 7.1.2.2.

2.2.4 Grounding The EDNS and EDSS power supply systems are operated ungrounded. Neither the positive nor the negative leg is grounded during normal operation. Therefore, a connection to ground on either the positive or negative leg does not change the DC system voltage; it is only referenced to ground at that point. However, structures and components of the EDSS and EDNS are connected to the station ground grid to provide personnel and equipment protection.

The EDSS and EDNS designs incorporate ground detection features to identify when a connection to ground occurs on either the positive or negative leg of a DC system.

2 8.3-38 Revision 4

Highly Reliable Direct Current Power System The surveillance and testing of the EDSS structures, systems, and components are based on the augmented provisions in Reference 8.3-1. Periodic inspection and testing is performed on the EDSS for operational, commercial, and plant investment protection purposes.

The EDSS is designed to permit appropriate periodic inspection and testing to assess the operability and functionality of the systems and the condition of their components.

Specifically, the EDSS design allows for removing portions of the system from operation without affecting continued operation of the plant. Protection devices are capable of being tested, calibrated, and inspected.

Preoperational tests are conducted to confirm battery capacity and verify proper operation of the EDSS. These tests are within the scope of the initial test program described in Section 14.2.

Normal Direct Current Power System Periodic inspection and testing is performed on the EDNS for operational, commercial, and plant investment protection purposes.

The EDNS is designed to permit inspection and testing to assess the operability and functionality of the systems and the condition of their components. The EDNS design allows a portion of the system to be removed from service without affecting continued operation of the plant.

Preoperational tests are conducted in accordance with manufacturer's instructions to confirm battery capacity and verify proper operation of the equipment.

2.4 Instrumentation and Controls The MCR and remote shutdown station monitoring and control of certain onsite DC power system components is provided by the plant control system and the module control system. The EDSS-C and EDSS-MS bus voltages are PAM type D variables that are monitored by the plant protection system and module protection system respectively, and displayed on the SDIS as described in Section 7.1.

Highly Reliable Direct Current Power System Each EDSS subsystem includes indications for DC bus voltage, battery current during charging and discharging, battery charger output current, and battery charger output voltage. Similarly, each battery and battery charger provides alarms and indications for high and low battery voltage, high and low DC bus voltage, battery charger undervoltage, battery discharge alarm, battery charger input and output breaker open alarms, and a high impedance ground fault detector. The EDSS includes provisions for automatic indication of system status in the main control room. The design of the EDSS status indication is consistent with the surveillance and test requirements of IEEE 2 8.3-39 Revision 4

and alarms.

Each EDSS-C and EDSS-MS battery has a battery monitor connected which provides continuous monitoring of EDSS battery performance characteristics, including temperature deviations, discharges, and voltage excursions that exceed predefined tolerances.

The EDSS includes augmented design provisions for the location of indicators and controls that conform to IEEE Standard 308-2001 (Reference 8.3-15) as described in Reference 8.3-1.

Normal Direct Current Power System Each EDNS subsystem includes indications for DC bus voltage, battery charging and discharging current, battery charger output current, and battery charger output voltage. Similarly, each primary and standby battery and battery charger (where provided) provides alarms and indications for high and low battery voltage, high and low DC bus voltage, battery charger undervoltage, battery discharge alarm, battery charger input and output breaker open alarms, and a high impedance ground fault detector.

3 References 8.3-1 NuScale Power, LLC, "Safety Classification of Passive Nuclear Power Plant Electrical Systems," TR-0815-16497-P-A, Rev. 1.

8.3-2 Insulated Cable Engineers Association, "Ampacities of Cables Installed in Cable Trays," ICEA P-54-440 (NEMA WC 51) - 2009, Carrollton, GA.

8.3-3 National Fire Protection Association, "National Electric Code," NFPA 70-2014, Quincy, MA.

8.3-4 Institute of Electrical and Electronics Engineers, "IEEE Recommended Practice for Protection and Coordination of Industrial and Commercial Power Systems (IEEE Buff Book)," IEEE Standard 242-2001, Piscataway, NJ.

8.3-5 Institute of Electrical and Electronics Engineers, "IEEE Design Guide for Electric Power Service Systems for Generating Stations," IEEE Standard 666-1991, Piscataway, NJ.

8.3-6 Institute of Electrical and Electronics Engineers, "IEEE Recommended Practice for Maintenance, Testing, and Replacement of Vented Lead-Acid Batteries for Stationary Applications," IEEE Standard 450-2010, Piscataway, NJ.

8.3-7 Institute of Electrical and Electronics Engineers, "IEEE Guide for Generating Station Grounding," IEEE Standard 665-1995, Piscataway, NJ.

2 8.3-40 Revision 4

Standard 1050-1996, New York, NY.

8.3-9 Institute of Electrical and Electronics Engineers, "IEEE Application Guide for Surge Protection of Electric Generating Plants," IEEE Standard C62.23-1995, Piscataway, NJ.

8.3-10 Institute of Electrical and Electronics Engineers, "IEEE Guide for Safety in AC Substation Grounding," IEEE Standard 80-2013, Piscataway, NJ.

8.3-11 Operation Technology Inc., "Electrical Transient Analyzer Program (ETAP),"

Release 14.1, 2016, Invine, CA.

8.3-12 Institute of Electrical and Electronics Engineers, "IEEE Recommended Practice for Sizing Lead Acid Batteries for Stationary Applications," IEEE Standard 485-1997, Piscataway, NJ.

8.3-13 Institute of Electrical and Electronics Engineers, "IEEE Recommended Practice for the Design of DC Auxiliary Power Systems for Generating Stations," IEEE Standard 946-2004, Piscataway, NJ.

8.3-14 Electric Power Research Institute, "Utility Requirements Document" (URD),

Approved Version 13, Volume III, Passive Plant, Chapter 11, "Electric Power Systems," Palo Alto, CA.

8.3-15 Institute of Electrical and Electronics Engineers Standard 308-2001, "IEEE Standard Criteria for Class 1E Power Systems for Nuclear Power Generating Stations," IEEE Standard 308-2001, Piscataway, NJ.

8.3-16 Institute of Electrical and Electronics Engineers, "IEEE Standard Criteria for Independence of Class 1E Equipment and Circuits," IEEE Standard 384-1992, New York, NY.

8.3-17 Institute of Electrical and Electronics Engineers, "IEEE Recommended Practice for Installation Design and Installation of Valve-Regulated Lead-Acid Batteries for Stationary Applications," IEEE Standard 1187-2013, New York, NY.

8.3-18 Institute of Electrical and Electronics Engineers, "IEEE Recommended Practice for Maintenance, Testing, and Replacement of Valve-Regulated Lead-Acid (VRLA) Batteries for Stationary Applications," IEEE Standard 1188-2005, New York, NY.

8.3-19 Institute of Electrical and Electronics Engineers, "IEEE Standard Criteria for Safety Systems for Nuclear Power Generating Stations, IEEE Standard 603-1991, Piscataway, NJ.

8.3-20 Institute of Electrical and Electronics Engineers, "IEEE Standard Application of the Single-Failure Criterion to Nuclear Power Generating Station Safety Systems," IEEE Standard 379-2000, Piscataway, NJ.

2 8.3-41 Revision 4

Systems, IEEE Standard 338-1987, Piscataway, NJ.

8.3-22 Institute of Electrical and Electronics Engineers, "IEEE Recommended Practice for Installation Design and Installation of Vented Lead-Acid Batteries for Stationary Applications, IEEE Standard 484-2002, reaffirmed in 2008, Piscataway, NJ.

8.3-23 Institute of Electrical and Electronics Engineers, "IEEE Standard for AC High-Voltage Circuit Breakers Rated on a Symmetrical Current Basis - Preferred Ratings and Related Required Capabilities for Voltages Above 1000 V," IEEE Standard C37.06-2009, New York, NY.

8.3-24 Institute of Electrical and Electronics Engineers, "IEEE Standard for AC High-Voltage Generator Circuit Breakers Rated on a Symmetrical Current Basis -

Amendment 1: Supplement for Use with Generators Rated 10-100 MVA," IEEE Standard C37.013a-2007, New York, NY. (Amendment to IEEE Std C37.013-1997).

8.3-25 Institute of Electrical and Electronics Engineers, "IEEE Standard for Electrical Penetration Assemblies in Containment Structures for Nuclear Power Generating Stations," IEEE Standard 317-1983, New York, NY.

8.3-26 Institute of Electrical and Electronics Engineers, "IEEE Standard Criteria for the Protection of Class 1E Power Systems and Equipment Nuclear Power Generating Stations," IEEE Standard 741-1997, New York, NY.

2 8.3-42 Revision 4

Equipment Ratings generators Rated 57.5 MVA Rated voltage - 13.8 kV Power factor - 85%

Efficiency - 95%

2 pole, 3600 RPM S - main power transformers 3 phase, 2 winding, HV - wye, LV - delta Primary voltage - 13.8 kV Secondary voltage - ((345 kV))

67 / 89 / 112 MVA Z = 12% on 67 MVA base, +/- 7.5%

Solid ground on wye (HV)

Type - liquid fill S - unit auxiliary transformers 3 phase, 2 winding, Primary voltage - 13.8 kV (delta)

Secondary voltage - 4.16 kV (wye) 12/16/20 MVA Z=8%,on 12 MVA base, +/- 7.5%

Resistance ground on wye (LV)

Type - liquid fill

- station service transformers 3 phase, 2 winding Primary voltage - 4.16 kV (delta)

Secondary voltage - 480 V (wye) 36 transformers rated 1.5/2.0 MVA (AA/FA) 16 transformers rated 2.5/3.33 MVA (AA/FA)

Z=5.75, +/- 7.5%

High resistance ground on wye (LV)

Type - dry S - 13.8 kV switchgear and breakers Bus continuous current - 5000 A Bus bracing - 80 kA symmetrical RMS Bus bracing - 134 kA asymmetrical RMS Breaker continuous current - 3000A Breaker interrupting rating - 63 kA Breakers - 3 cycle S - 4.16 kV switchgear and breakers Bus continuous current - 3000 A Bus bracing - 50 kA symmetrical RMS Bus bracing - 78 kA asymmetrical RMS Breaker continuous current - 3000 A (main and tie)

Breaker continuous current - 1200 A (feeder)

Breaker interrupting rating - 50 kA S cable bus Shielded power cable with appropriate stress cone materials at either end Cable bus ampacity - 3000A

- 480 V switchgear and breakers Bus continuous current - 3200 A for 48 load centers, 4000 A for 8 load centers Bus bracing - 65 kA symmetrical RMS Bus bracing - 86.5 kA asymmetrical RMS Breaker continuous current - 4000 A / 3200 A (main and tie)

Breaker continuous current - 800 A (feeder)

Breaker interrupting rating - 65 kA

- 480 V MCCs Bus continuous current - 600, 800, or 1200 A Bus bracing - 65 kA symmetrical RMS Bus bracing - 86.5 kA asymmetrical RMS ELVS MCC.B-6000 Series - normal and alternate feed (normal from ELVS load center, alternate from BPSS load center)

ELVS motor control center - single feed from ELVS load center 2 8.3-43 Revision 4

Load Description Required # Rated Voltage Operating Load Total Load of Equipment (Vac) (kVA) (kVA) mical and volume control system (CVCS) - 1 460 48.76 48.76 eup pump (50 hp) ainment flooding and drain system(CFDS) - 1 460 9.75 9.75 rifugal pump (10 hp)

S-MS division I, channel A - battery charger 6.25 1 per module 480 9.30 111.60 125 Vdc, 24 hr S-MS division I, channel C - battery charger 1 per module 480 13.90 166.80 5 kW, 125 Vdc, 72 hr S-MS division II, channel B - battery charger 1 per module 480 13.90 166.80 5 kW, 125 Vdc, 72 hr S-MS division II, channel D - battery charger 1 per module 480 9.30 111.60 kW, 125 Vdc, 24 hr S-C division I Common - battery charger 12.5 1 480 18.50 18.50 125 Vdc, 72 hr S-C division II Common - battery charger 12.5 1 480 18.50 18.50 125 Vdc, 72 hr ess Sampling System (PSS) - Containment 12 480 4.88 58.56 pling System (CSS) load (5 hp) n addition - boric acid supply pump (5 hp) 1 460 4.88 4.88 S - CRVS standby CHWS chiller (267.8 kW) 1 480 315.06 315.06 S - CRVS standby CHWS chiller remote 2 460 24.00 48.00 ensing unit (20.40 kW)

S - CRVS standby chiller chilled water pump (5 1 460 4.88 4.88 S - CRVS supply air handling unit A&B (75 hp) 1 460 73.14 73.14 S - CRVS supply air handling unit - preheat coil 1 480 168 168 (168 kW)

S - CRVS filter unit fan motor (20 hp) 1 460 19.50 19.50 S - CRVS filter unit heating coil (148 kW) 1 480 148.00 148.00 S - RXB North - regulating transformer 480: 1 480 50.29 50.29 208 Vac, 225 kVA S - RXB South - regulating transformer 480: 1 480 50.29 50.29 208 Vac, 225 kVA S - CRB - regulating transformer 480: 120/208 1 480 72.12 72.12 100 kVA S - RWB - regulating transformer 480: 120/208 1 480 10.59 10.59 25 kVA S - MPS & battery room air supply fan (5 HP) 1 per module 460 4.88 58.56 S - MPS & battery room DX coil condenser 1 per module 460 13.57 162.84 1 kVA) 2 8.3-44 Revision 4

le 8.3-3: Highly Reliable Direct Current Power System Major Component Data Nominal Values Battery A/D Channels - 542 AH to 1.75 VPC, 24-hr discharge EDSS - MS B/C Channels - 1039 AH to 1.75 VPC, 72-hr discharge (RXB - Elev. 75 ft)

Battery Div I /Div II - 2303 AH to 1.75 VPC, 72-hr discharge EDSS - C (CRB - Elev 50 ft)

Battery Charger A/D Channels - 6.25 kW, 50 A DC output EDSS - MS B/C Channels - 9.375 kW, 75 A DC output (RXB Bldg - Elev 86 ft)

Battery Charger Div I /Div II - 12.5 kW, 100 A DC output EDSS - C (CRB - Elev 50 ft)

DC Switchgear A/D Channels -100 A EDSS - MS B/C Channels - 225 A (RXB Bldg - Elev 86 ft)

DC Switchgear Div I /Div II - 225 A EDSS - C (CRB - Elev 50 ft)

Battery Monitor Continuously monitors battery performance and provides alarms for battery discharges, voltage excursions, and temperature deviations exceeding tolerances.

EDSS - MS (RXB - Elev 75 ft)

EDSS - C (CRB - Elev 50 ft)

Fused Disconnect Switch Provides a means to disconnect feeder and branch circuits. Switches include fusible overcurrent protection.

EDSS - MS (RXB - Elev 86 ft)

EDSS - C (CRB - Elev 50 ft)

Fused Transfer Switch Provides a means to manually establish connection between battery and DC bus, battery test terminals, or battery charger. Switches include fusible overcurrent protection.

EDSS - MS (RXB - Elev 75 ft)

EDSS-C (CRB - Elev 50 ft) 2 8.3-45 Revision 4

Load Description (Division I)2 Battery Load Time Load Amp-hour (W, amps) Period Classification3 Control Room Envelope Isolation Damper #1 179.00 1.43 60 sec Momentary 0.02 Control Room Envelope Isolation Damper #2 179.00 1.43 60 sec Momentary 0.02 Control Room Envelope Isolation Damper #3 179.00 1.43 60 sec Momentary 0.02 Control Room Envelope Isolation Damper #4 179.00 1.43 60 sec Momentary 0.02 Main Air Delivery Valve 40.00 0.32 60 sec Momentary 0.01 Pressure Relief Valve 40.00 0.32 60 sec Momentary 0.01 Air Duct Radiation Monitor 75.00 0.60 72 hr Continuous 43.20 abinet 158.82 1.27 72 hr Continuous 91.44 ensor Input Power 18.07 0.14 72 hr Continuous 10.08 Cabinet 35.29 0.28 72 hr Continuous 20.16 Main Control Room Displays (module) 762.35 6.10 72 hr Continuous 439.20 Main Control Room Displays (common) 63.53 0.51 72 hr Continuous 36.72 eactor Pool Area Radiation Monitor #1 35.00 0.28 72 hr Continuous 20.16 eactor Pool Area Radiation Monitor #2 35.00 0.28 72 hr Continuous 20.16 ain Control Room Emergency Lighting 440.00 3.52 72 hr Continuous 253.44 battery monitor 50.00 0.40 72 hr Continuous 28.80 Continuous Load (ILC) 1673.06 13.38 Noncontinuous Load (ILN) 0.00 0.00 Momentary Load (ILM) 796.00 6.36 l Amp-Hours Removed (Q) 963.46 loads assumed for each divisional battery are estimated nominal values. These nominal loads are based on assumed ment vendor information and best engineering load estimates.

applicable to Division II mentary loads are de-energized by PPS in the event of a loss of AC power to the EDSS-C battery chargers.

2 8.3-46 Revision 4

Nominal Loads1 Load Description Load Time Load Amp-hour (W, amps) Period Classification2 EDSS-MS Nominal Loads (Channel A)3 S Makeup Containment Isolation Valve (CIV) 100.00 0.80 60 sec Momentary 0.01 S Letdown CIV 100.00 0.80 60 sec Momentary 0.01 S PZR Spray CIV 100.00 0.80 60 sec Momentary 0.01 S High Point Degas CIV 100.00 0.80 60 sec Momentary 0.01 Steam CIV 100.00 0.80 60 sec Momentary 0.01 Steam Bypass CIV 4 0.00 0.00 - - 0.00 S Actuation Valve 1 100.00 0.80 60 sec Momentary 0.01 S Actuation Valve 2 100.00 0.80 60 sec Momentary 0.01 CIC 100.00 0.80 60 sec Momentary 0.01 WS Supply CIV 100.00 0.80 60 sec Momentary 0.01 WS Return CIV 100.00 0.80 60 sec Momentary 0.01 S CIV 100.00 0.80 60 sec Momentary 0.01 CIV 100.00 0.80 60 sec Momentary 0.01 Reactor Recirculation Valve (RRV) 250.00 2.00 24 hr Continuous 48.00 Reactor Vent Valve (RVV) #1 250.00 2.00 24 hr Continuous 48.00 Reactor Vent Valve (RVV) #3 250.00 2.00 24 hr Continuous 48.00 Cabinet (SC/TD) 89.41 0.72 24 hr Continuous 17.28 Cabinet (Gateway) 104.71 0.84 24 hr Continuous 20.16 Cabinet (RTS/ESFAS) 176.47 1.41 24 hr Continuous 33.84 Sensor Input Power 60.59 0.48 24 hr Continuous 11.52 Cabinet 100.00 0.80 24 hr Continuous 19.20 Battery Monitor 50.00 0.40 24 hr Continuous 9.60 l Continuous Load (ILC) 1331.18 10.65 l Noncontinuous Load (ILN) 0.00 0.00 l Momentary Load (ILM) 1200.00 9.60 al Amp-Hours Removed (Q) 255.72 EDSS-MS Nominal Loads (Channel C)5 S Makeup CIV 100.00 0.80 60 sec Momentary 0.01 S Letdown CIV 100.00 0.80 60 sec Momentary 0.01 S PZR Spray CIV 100.00 0.80 60 sec Momentary 0.01 S High Point Degas CIV 100.00 0.80 60 sec Momentary 0.01 Steam CIV 100.00 0.80 60 sec Momentary 0.01 Steam Bypass CIV4 0.00 0.00 - - 0.00 S Actuation Valve 1 100.00 0.80 60 sec Momentary 0.01 S Actuation Valve 2 100.00 0.80 60 sec Momentary 0.01 CIV 100.00 0.80 60 sec Momentary 0.01 WS Supply CIV 100.00 0.80 60 sec Momentary 0.01 WS Return CIV 100.00 0.80 60 sec Momentary 0.01 S CIV 100.00 0.80 60 sec Momentary 0.01 CIV 100.00 0.80 60 sec Momentary 0.01 Reactor Recirculation Valve (RRV) 250.00 2.00 24 hr Noncontinuous 48.00 Reactor Vent Valve (RVV) #1 250.00 2.00 24 hr Noncontinuous 48.00 Reactor Vent Valve (RVV) #3 250.00 2.00 24 hr Noncontinuous 48.00 Cabinet (SC/TD) 118.82 0.95 72 hr Continuous 68.40 Cabinet (Gateway) 104.71 0.84 72 hr Continuous 60.48 2 8.3-47 Revision 4

Load Description Load Time Load Amp-hour (W, amps) Period Classification2 Cabinet (RTS/ESFAS) 176.47 1.41 24 hr Noncontinuous 33.84 Sensor Input Power 60.59 0.48 72 hr Continuous 34.56 Cabinet 100.00 0.80 72 hr Continuous 57.60 Bioshield Radiation Monitor 120.00 0.96 72 hr Continuous 69.12 Battery Monitor 50.00 0.40 72 hr Continuous 28.80 l Continuous Load (ILC) 554.12 4.43 l Noncontinuous Load (ILN) 926.47 7.41 l Momentary Load (ILM) 1200.00 9.60 al Amp-Hours Removed (Q) 496.92 e loads assumed for each divisional battery are estimated nominal values. These nominal loads are based on assumed uipment vendor information and best engineering load estimates.

mentary loads are de-energized by MPS in the event of a loss of AC power to the EDSS-MS battery chargers.

o applicable to Channel D in steam bypass CIVs are considered to be de-energized during normal operation.

o applicable to Channel B 2 8.3-48 Revision 4

Indication Alarm Parameter Control Room Local Control Room Local ry current (charge / discharge) X ured by battery monitor ry charger output current X us voltage X X ry charger output voltage X us undervoltage alarm (27 relay) X ystem ground alarm X X ry breaker / switch open alarm X ry charger output breaker open X ry charger DC output failure alarm X ry charger AC power failure alarm X ry charger low DC voltage alarm X ger high DC voltage shutdown (relay) X ry test breaker closed alarm X

/ low battery voltage alarms as X ured by battery monitor DC bus voltage alarm (59 relay) X ry discharge alarm as measured by X ry monitor ry charger input breaker alarm X ry charger overload alarm X ry temperature alarm as measured by X ry monitor 2 8.3-49 Revision 4

Analysis mponent Function Failure Mode / Effect

• Failure Mechanism Conclusion ery Provide 125 Vdc power No output / Charger fault Acceptable - No rger to DC switchgear while (A) System load supplied by conceivable single maintaining battery redundant charger of Failure of internal failures result in loss of charge affected channel/division. components including interfacing safety (B) None. AC input breaker, DC system functions. All output breaker, failures are detectable.

Loss of input / resistors, silicon (A) System load supplied by controlled rectifiers, redundant charger of transformer, relays, affected channel/division. fuses, diodes, voltage (B) None. regulators, etc.

Low output / Misuse (A) Redundant charger able to compensate on affected Design deficiency channel/division.

(B) None. Quality defect Erratic output /

(A) Redundant charger able to compensate on affected channel/division. The EDSS may operate at abnormal voltage levels.

(B) None.

High output voltage /

(A) Associated channel/division operates at elevated voltage.

(B) None.

Loss of communication link /

(A) Assumed loss of both linked chargers. Batteries of affected channel/division begin discharging.

(B) None.

Loss of blocking functionality /

(A) Redundant charger available to compensate on affected channel/division. Assumes forward current flow is not permitted through affected charger.

(B) Affected charger may become load on batteries, thus reducing battery discharge time.

2 8.3-50 Revision 4

mponent Function Failure Mode / Effect

• Failure Mechanism Conclusion ery Supply power to 125 No output (battery fault) / Container cracks Acceptable - No Vdc switchgear and (A) None. Fused transfer or conceivable single various loads disconnect switches Dryout of cell failures result in loss of available to clear the fault. interfacing safety (B) System load is supplied by Excessive temperature system functions. All redundant battery of failures are detectable.

affected channel/division. Thermal runaway Failed battery may temporarily draw current High cycling rates from redundant battery.

Defective post seals Low output /

(A) None. Strap corrosion (B) Redundant battery available to compensate. Excessive plate sulfation

/ growth Post / connection hardware problems Personnel error Design deficiency Quality defect Vdc Supply 125 Vdc to No input / Grounding of positive Acceptable - No chgear / various loads (A,B) Loss of power to all or negative leg conceivable single division/channel loads. failures result in loss of Bus fault interfacing safety Bus failure / system functions. All (A,B) Loss of power to all Personnel error failures are detectable.

division/channel loads.

Design deficiency Power remains available with a single ground.

Quality defect 2 8.3-51 Revision 4

mponent Function Failure Mode / Effect

• Failure Mechanism Conclusion ed transfer Provide continuity or Indavertent opening (blown Wear / fatigue/ Acceptable - No ch point isolation from fuse) / deformation / conceivable single battery, test (A) Reduced load on battery degradation of fuse failures result in safety connection, or battery chargers. holder system actuation or loss charger (B) System load supplied by of interfacing safety redundant battery of Corrosion system functions. All affected channel/division. failures are detectable.

Oxidation Fails to interrupt /

(A,B) Fusible disconnect located Equipment load cycling between transfer switch and DC bus available to clear/interrupt. Heat generated by surrounding components Embrittlement of fuse element Personnel error Design deficiency Quality defect 2 8.3-52 Revision 4

mponent Function Failure Mode / Effect

• Failure Mechanism Conclusion ery Continuously monitor High output parameter / Device failure Acceptable - No nitor performance indication / alarm / conceivable single characteristics of (A,B) Erroneous local and MCR Misuse failures result in battery system indication / alarms related to safety-related system affected battery. Redundant Design deficiency actuation or loss of battery monitor and both interfacing batteries of affected Quality defect safety-related system channel/division remain functions. All failures available. are detectable.

Low output parameter /

indication/ alarm /

(A,B) Erroneous local and MCR indication / alarms related to affected battery. Redundant battery monitor and both batteries of affected channel/division remain available.

Output parameter/indication fails as is /

(A,B) Erroneous local and MCR indication / alarms related to affected battery. Redundant battery monitor and both batteries of affected channel/division remain available.

Loss of output/indication/ alarm function /

(A,B) Loss of ability to monitor/alarm affected battery operating parameters.

Redundant battery monitor and both batteries of affected channel/division remain available 2 8.3-53 Revision 4

mponent Function Failure Mode / Effect

• Failure Mechanism Conclusion bus Operate when input Fail to operate/output / Failure of contacts, coils, Acceptable - No ervoltage voltage drops below a (A,B) None. If undervoltage or various other internal conceivable single predetermined value condition is present, batteries components failures result in safety y continue to discharge. system actuation or loss Mechanical failure of interfacing safety Spurious operation/output / system functions. All (A,B) No effect on EDSS Deviation of settings failures are detectable.

operation. Erroneous MCR alarm.

Misuse Personnel error Design deficiency Quality defect bus Operate when input Fail to operate/output / Failure of contacts, coils, Acceptable - No rvoltage voltage exceeds a (A,B) If overvoltage condition is or various other internal conceivable single predetermined value present, associated channel / components failures result in safety y division operates at elevated system actuation or loss voltage. Mechanical failure of interfacing safety system functions. All Spurious operation/output / Deviation of settings failures are detectable.

(A,B) No effect on EDSS operation. Erroneous MCR alarm. Misuse Personnel error Design deficiency Quality defect bus Operate on failure of Fail to operate/output / Failure of contacts, coils, Acceptable - No und fault the insulation of (A,B) None. Assumes only one or various other internal conceivable single apparatus to ground system ground is present on components failures result in safety y associated channel / division. system actuation or loss Mechanical failure of interfacing safety Spurious operation/output / system functions. All (A,B) No effect on EDSS Deviation of settings failures are detectable.

operation. Erroneous MCR alarm.

Misuse Personnel error Design deficiency Quality defect 2 8.3-54 Revision 4

mponent Function Failure Mode / Effect

• Failure Mechanism Conclusion bus Continuously measure Low output / (A,B) No effect on Misuse Acceptable - No meter DC bus voltage EDSS operation. Erroneous conceivable single local/remote PAM (Type D Personnel error failures result in safety variable) indication for system actuation or loss associated DC bus. Design deficiency of interfacing safety system functions. All High output / (A,B) No effect on Quality defect failures are detectable.

EDSS operation. Erroneous local/remote PAM (Type D variable) indication for associated DC bus.

Fail as-is / (A,B) No effect on EDSS operation. Erroneous local/remote PAM (Type D variable) indication for associated DC bus.

ery Continuously measure Low output / (A,B) No effect on Misuse Acceptable - No rger DC current EDSS operation. Upstream conceivable single meter battery charger provides DC Personnel error failures result in safety current indication / system actuation or loss measurement. Design deficiency of interfacing safety system functions. All High output / (A,B) No effect on Quality defect failures are detectable.

EDSS operation. Upstream battery charger provides DC current indication /

measurement.

Fail as-is / (A,B) No effect on EDSS operation. Upstream battery charger provides DC current indication / measurement.

2 8.3-55 Revision 4

mponent Function Failure Mode / Effect

• Failure Mechanism Conclusion ble Provide circuit Spurious operation (blown fuse)/ Wear / fatigue/ Acceptable - No onnect continuity and deformation / conceivable single rger-to-bus protection between (A) Loss of ability to supply DC degradation of fuse failures result in safety DC bus and associated bus from upstream battery holder system actuation or loss load charger. DC bus supplied by of interfacing safety redundant charger of Corrosion system functions. All affected channel/division. failures are detectable.

(B) None. Oxidation Fails to close / Equipment load cycling (A) Loss of ability to supply DC bus from upstream battery Heat generated by charger. DC bus supplied by surrounding redundant charger of components affected channel/division.

(B) None. Embrittlement of fuse element Fails to open /

(A) Continued loading on Misuse battery charger. Upstream battery charger output Design deficiency breaker available to open/clear/interrupt. Quality defect (B) None. Upstream battery charger output breaker available to open/interrupt.

Fails to interrupt on opening /

(A) Continued loading on battery charger. Upstream battery charger output breaker available to open/clear/interrupt.

(B) None. Upstream battery charger output breaker available to open/interrupt.

2 8.3-56 Revision 4

mponent Function Failure Mode / Effect

• Failure Mechanism Conclusion ble Provide circuit Spurious operation (blown fuse)/ Wear / fatigue/ Acceptable - No onnect continuity and (A) Reduced load on battery deformation / conceivable single sfer protection between chargers. degradation of fuse failures result in safety ch- to- bus battery transfer switch (B) DC bus supplied by holder system actuation or loss and DC bus redundant battery of of interfacing safety affected channel/division Corrosion system functions. All failures are detectable.

Fails to close / Oxidation (A) Reduced load on battery chargers. Equipment load cycling (B) DC bus supplied by redundant battery of Heat generated by affected channel/division surrounding components Fails to open /

(A) Continued float charging of Embrittlement of fuse battery. Upstream transfer element switch located between battery and fusible Misuse disconnect available to open/interrupt. Design deficiency (B) Continued loading on battery. Upstream transfer Quality defect switch located between battery and fusible disconnect available to open/interrupt.

Fails to interrupt on opening /

(A) Continued float charging of battery. Upstream transfer switch located between battery and fusible disconnect available to open/interrupt.

(B) Continued loading on battery. Upstream transfer switch located between battery and fusible disconnect available to open/interrupt.

2 8.3-57 Revision 4

mponent Function Failure Mode / Effect

• Failure Mechanism Conclusion ble Provide circuit Spurious operation (blown fuse)/ Wear / fatigue/ Acceptable - No onnect continuity and (A, B) Loss of ability to supply deformation / conceivable single protection between power to associated load. degradation of fuse failures result in loss of

-to-load DC bus and associated holder interfacing safety load Fails to close / system functions. All (A,B) Loss of ability to supply Corrosion failures are detectable.

power to associated load.

Oxidation Fails to open /

(A) Continued loading on Equipment load cycling battery chargers. Upstream protection devices available Heat generated by to open/interrupt. surrounding (B) Continued loading on components batteries. Upstream protection devices available Embrittlement of fuse to open/interrupt. element Fails to interrupt on opening / Misuse (A) Continued loading on battery chargers. Upstream Design deficiency protection devices available to open/interrupt. Quality defect (B) Continued loading on batteries. Upstream protection devices available to open/interrupt.

ductors Maintain circuit Loss of conductor continuity / Failed structural Acceptable - No rger to bus integrity between (A) System load supplied by support conceivable single termination points redundant charger of failures result in safety affected channel/division. Insulation degradation system actuation or loss (B) None. of interfacing safety Physical damage to system functions. All Conductor to external ground conductor or connector failures are detectable.

short circuit /

(A) System load supplied by Misuse redundant charger of affected channel/division. Design Deficiency (B) None.

Quality defect Loss of insulation resistance /

(A) System load supplied by redundant charger of affected channel/division.

(B) None.

Hot short /

(A,B) None 2 8.3-58 Revision 4

mponent Function Failure Mode / Effect

• Failure Mechanism Conclusion ductors Maintain circuit Loss of conductor continuity / Failed structural Acceptable - No ery to bus integrity between (A) Reduced load on battery support conceivable single termination points chargers. failures result in safety (B) System load supplied by Insulation degradation system actuation or loss redundant battery of of interfacing safety affected channel/division. Physical damage to system functions. All conductor or connector failures are detectable.

Conductor to external ground short circuit / Misuse (A) Reduced load on battery chargers. Design Deficiency (B) System load supplied by redundant battery of Quality defect affected channel/division.

Loss of insulation resistance /

(A) Reduced load on battery chargers.

(B) System load supplied by redundant battery of affected channel/division.

Hot short /

(A,B) None ductors Maintain circuit Loss of conductor continuity / Failed structural Acceptable - No rger to integrity between (A,B) None support conceivable single termination points failures result in safety Conductor to external ground Insulation degradation system actuation or loss short circuit / of interfacing safety (A,B) None Physical damage to system functions. All conductor or connector failures are detectable.

Loss of insulation resistance /

(A,B) None Misuse Hot short / Design Deficiency (A,B) None Quality defect

) and (B) consider plant operating conditions as follows:

(A) Normal highly reliable DC power system AC power supply available (B) Loss of normal highly reliable DC power system AC power supply. The BPSS unavailable.

e effects associated with conductor bus-to-load failures are bounded by the effects associated with failure of the tream bus-to-load fusible disconnect switches and are not separately included in the FMEA.

2 8.3-59 Revision 4

Values NS Component EDNS Subsystem(s) Nominal Values batteries All Type: VRLA RXB North/South Single string, 120 cells, 250 Vdc 1080 AH at 8-hour rate to 1.75 V/cell at 77°F discharge rate CRB Single string, 60 cells, 125 Vdc 1320 AH at 8-hour rate to 1.75 V/cell at 77°F discharge rate RWB Single string, 60 cells, 125 Vdc 345 AH at 8-hour rate to 1.75 V/cell at 77°F discharge rate Turbine Building North/South Single string, 120 cells, 250 Vdc 1320 AH at 8-hour rate to 1.75 V/cell at 77°F discharge rate Yard PDC 1/PDC 2 Two strings, 60 cells/string, 125 Vdc 2160 AH at 8-hour rate to 1.75 V/cell at 77°F discharge rate Yard PDC 3/PDC 4 Single string, 60 cells, 125 Vdc 1080 AH at 8-hour rate to 1.75 V/cell at 77°F discharge rate Yard PDC 5/PDC 6 Single string, 60 cells, 125 Vdc 480 AH at 8-hour rate to 1.75 V/cell at 77°F discharge rate Yard PDC 7/PDC 8 Single string, 60 cells, 125 Vdc 345 AH at 8-hour rate to 1.75 V/cell at 77°F discharge rate ery chargers All Input voltage: 480 Vac, 3-phase RXB North/South Output voltage: 250 Vdc Output current: 800 A CRB Output voltage: 125 Vdc Output current: 800 A RWB Output voltage: 125 Vdc Output current: 150 A Turbine Building North/South Output voltage: 250 Vdc Output current: 800 A Yard PDC 1/PDC 2 Output voltage: 125 Vdc Output current: 300 A Yard PDC 3/PDC 4 Output voltage: 125 Vdc Output current: 200 A Yard PDC 5/PDC 6 Output voltage: 125 Vdc Output current: 150 A Yard PDC 7/PDC 8 Output voltage: 125 Vdc Output current: 200 A istribution buses All Individual bus ratings specified below RXB North/South Bus voltage: 250 Vdc Current rating: 1200 A CRB Bus voltage: 125 Vdc Current rating: 1200 A RWB Bus voltage: 125 Vdc Current rating: 400 A Turbine Building North/South Bus voltage: 250 Vdc Current rating: 1200 A Yard PDC 1/PDC 2 Bus voltage: 125 Vdc Current rating: 600 A Yard PDC 3/PDC 4 Bus voltage: 125 Vdc Current rating: 400 A Yard PDC 5/PDC 6 Bus voltage: 125 Vdc Current rating: 400 A Yard PDC 7/PDC 8 Bus voltage: 125 Vdc Current rating: 400 A 2 8.3-60 Revision 4

NS Component EDNS Subsystem(s) Nominal Values rters All Output voltage: 120/208 Vac, 3-phase RXB North/South Input voltage: 250 Vdc Rating: 200 KVA CRB Input voltage: 125 Vdc Rating: 100 KVA RWB Input voltage: 125 Vdc Rating: 20 KVA Turbine Building North/South Input voltage: 250 Vdc Rating: 40 KVA Yard PDC 1/PDC 2 N/A - No DC-to-AC inversion in these EDNS subsystems Yard PDC 3/PDC 4 N/A - No DC-to-AC inversion in these EDNS subsystems Yard PDC 5/PDC 6 N/A - No DC-to-AC inversion in these EDNS subsystems Yard PDC 7/PDC 8 N/A - No DC-to-AC inversion in these EDNS subsystems age regulating All Input voltage: 480 Vac sformers Output voltage: 120/208 Vac, 3-phase RXB North/South Rating: 225 KVA CRB Rating: 100 KVA RWB Rating: 25 KVA Turbine Building North/South Rating: 50 KVA Yard PDC 1/PDC 2 N/A - No DC-to-AC inversion in these EDNS subsystems Yard PDC 3/PDC 4 N/A - No DC-to-AC inversion in these EDNS subsystems Yard PDC 5/PDC 6 N/A - No DC-to-AC inversion in these EDNS subsystems Yard PDC 7/PDC 8 N/A - No DC-to-AC inversion in these EDNS subsystems istribution buses All -

RXB North/South Current Rating: 800 A CRB Current Rating: 400 A RWB Current Rating: 225 A Turbine Building North/South Current Rating: 225 A Yard PDC 1/PDC 2 N/A - No DC-to-AC inversion in these EDNS subsystems Yard PDC 3/PDC 4 N/A - No DC-to-AC inversion in these EDNS subsystems Yard PDC 5/PDC 6 N/A - No DC-to-AC inversion in these EDNS subsystems Yard PDC 7/PDC 8 N/A - No DC-to-AC inversion in these EDNS subsystems 2 8.3-61 Revision 4

ble 8.3-9: FSAR Cross Reference for the Conditions of Applicability and NRC SER Limitations and Conditions for TR-0815-16497-P-A able 3-1 Section I FSAR Sections that Demonstrate Condition is Satisfied Condition Number Design Basis Event Assumptions

• 15.0.0.6.4 and 15.0.4 (72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> stabilized condition DBE end state without operator actions required)

• 15.0.0.6.5 (DBE analysis includes loss of electrical power)

• 8.4.2 (SBO Loss of AC and DC power for 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> duration)

.a .

• 3.9.4 (CRDS does not rely on electrical power)

• 8.4.2 (SBO reactor trip)

.b.

• 4.3.1.5 (Shutdown capability does not rely on electrical power)

• 15.6 (Decrease in inventory event analyses do not rely on electrical power or credit active injection sources)

• 8.4.2 (SBO does not rely on electrical power for shutdown or inventory control)

.c.

• 5.4.3.1 (DHRS function does not rely on electrical power)

• 6.3.1 (ECCS function does not rely on electrical power)

• 15.0.0.6.3 (DBE analysis does not credit electrical power for DHRS or ECCS functions)

• Table 15.0-2, Table 15.0-3, Table 15.0-4 (Fuel and core acceptance criteria confirm core cooling)

• 8.4.2 (SBO core cooling relies on DHRS and ECCS)

.d.

• 6.2.4.2.1 (CNV isolation function does not rely on electrical power)

• 8.4.3 (SBO containment integrity does not rely on electrical power)

.e.

• 6.2.1, 6.2.2, and 6.2.5.1. (Passive CNTS and UHS design does not include active ESF heat removal and combustible gas control systems)

• Table 15.0-2 (DBE thermal hydraulic acceptance criteria confirm containment peak pressure margin)

• 8.4.3 (No credit for active ESF heat removal for containment integrity in SBO analysis)

.f.

• 6.5.3 (Active fission product removal systems are not required)

• Table 15.0-12 (DBA radiological consequences show guidelines maintained)

.g.

• 5.2.2. 1 (Overpressure protection system does not rely on electrical power)

• 8.4.2 (SBO RPV pressure margin)

• Table 15.0-2 (DBE thermal hydraulic analyses confirm margin to RCS pressure acceptance criteria)

• See associated PAM FSAR references in items 2a-2c below.

.a

• 7.1.1.2.2 (PAM design)

• 8.4.2 (No credit for manual actions in SBO analysis)

.b

• 7.1.1.2.2 (PAM design)

.c

• 7.1.1.2.2 (PAM design)

• 9.1.3, 9.2.5.2 (UHS and SFP integrated passive cooling function does not rely on electrical power)

• 9.2.5.2.1 (SFP weir design maintains 10 feet in SFP above racks without active systems)

• 9.1.3, 9.2.5.2 (UHS and SFP integrated passive cooling function does not rely on electrical power)

• 9.2.5.2.1 (SFP weir design maintains 10 feet in SFP above racks without active systems)

• 9.1.4.2, 9.2.5.3 (UHS provides a minimum of 10 feet for shielding available during fuel handling)

• 6.4 (CRHS does not rely on electrical power)

• 8.4.3 (Main control room habitable during SBO without relying on electrical power) 2 8.3-62 Revision 4

able 3-1 Section I FSAR Sections that Demonstrate Condition is Satisfied Condition Number

• 3.11.2.1 (PAM environmental qualification)

• 3.11.4 (72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> loss of ventilation)

• Table 3C-3 (EDSS environment environment)

• 8.4.2, 8.4.3 (SBO mitigation equipment for 10 CFR 50.63 (DHRS and ECCS) is operable in SBO environment)

Active Fission Product Removal Systems

• 6.5.3 (Active fission product removal systems are not required to meet regulatory requirements)

Active Ventilation Systems Not Required to Mitigate the Consequences of Design Basis Accidents

• 9.4.2.3 (RBVS)

• 9.4.5 (No ESF ventilation in NuScale design)

Dose Analyses

• 15.0.3, Table 15.0-12 (No active ventilation systems are required to maintain offsite doses within applicable guidelines) able 3-1 Section II FSAR Sections Which Demonstrate Condition is Satisfied Condition Number gmented Provisions

• Table 8.3-10 mparative EDSS Reliability

• 8.3.2.1.1 (EDSS reliability evaluation) ergency Lighting Capability

• 8.4.3 (SBO emergency lighting)

• 9.5.1.2 (Fire protection)

• 9.5.3.2 (Emergency lighting design)

ER Condition Number FSAR Sections Which Demonstrate Condition is Satisfied G 1.155

• 8.3.2.2.2 (RG 1.155 part) eismic

• Table 3.2-1 (EDSS seismic classification)

• 8.3.2.1.1 (EDSS seismic design)

• 8.3.2.2.2 (EDSS GDC 2) perator Actions

• 7.1.1.2.2 (PAM design)

• 15.0.0.6.4, 18.6.2.2 (Operator actions not needed to support DBE analysis)

OO with ECCS actuation

• 15.0.0.6.3 (Condition 4.4) tuck rod safe shutdown

• 4.3.1.5 (Shutdown capability)

• 9.3.4.3 (CVCS safety evaluation)

• 15.0.6 (Return to power) 2 8.3-63 Revision 4

Augmented Provision FSAR Sections Which Demonstrate that Condition is Satisfied Table 3-2 of Reference 8.3-1) pliance with 10 CFR 50.55a(1)

• 8.3.2.2.2 (10 CFR 50.55a(h))

IEEE Standard 603-1991 ty Classification

• 8.3.2.1.1

• 8.3.2.2.2 (RG 1.32) ity Assurance

• 8.3.2.2.2 (RG 1.155) mic Qualification

• 8.3.2.1.1 (EDSS seismic design)

• 8.3.2.2.2 (GDC 2) ronmental Qualification

• 8.3.2.2.2 (GDC 4)

• 3.11.2.1 (mild environments)

• Appendix 3C and Table 3C-3 (EDSS rooms) eries

• 8.3.2.2.1 (Battery design) te Standby Power Sources

• 8.3.1.2.7 (SECY 94-084 and SECY 95-132) tification

• 8.3.2.1.1

• 8.3.2.2.2 (RG 1.32 and RG 1.75) pendence

• 8.3.2.1.1

• 8.3.2.2.2 (10 CFR 50.55a(h), RG 1.32, RG 1.75, and RG 1.128) le Failure Criterion

• 8.3.2.1.1

• 8.3.2.2.2 (RG 1.32 and RG 1.53) mon Cause Failure

• 8.3.2.1.1

• 8.3.2.2.2 (RG 1.32 and RG 1.53) rol of Access

• 8.3.2.1.1

• 8.3.2.2.2 (RG 1.232) ection

• 8.3.2.2.3 (Equipment Protection) er Quality

• 8.3.2.2.3 (Power Quality) tion of Indicators and Controls

• 8.3.2.2.2 (RG 1.32)

• 8.3.2.4 eillance and Testing

• 8.3.2.2.2 (RG 1.32, RG 1.41, RG 1.68, RG 1.118, RG 1.129, and Section 14.2) 8.3.2.3 i-Unit Station Considerations

• 8.3.2.2.2 (RG 1.32 and 1.81, GDC 5) 2 8.3-64 Revision 4

NuScale Final Safety Analysis Report Onsite Power Systems Figure 8.3-1: Station Single Line Diagram L1 TL 345 kV A BREAKER AND HALF SCHEME L2 TL 345 kV SWITCH YARD A

AAPS 1STG 2STG 3STG 4STG 5STG TO BUS 1011 7STG 8STG 9STG 10STG 11STG 6STG 12STG A I J K L M H I J K L M H O P Q R S N O P Q R S N TO BUS 1021 MPT MPT MPT MPT MPT MPT MPT MPT XF1011 XF1012 XF1013 XF1014 XF1021 XF1022 XF1023 XF1024

12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 (H1011) 13.8 kV (H1012) 13.8 kV (H1013) 13.8 kV (H1014) 13.8 kV (H1021) 13.8 kV (H1022) 13.8 kV (H1023) 13.8 kV (H1024) 13.8 kV 0A 0B UAT UAT UAT UAT UAT UAT UAT UAT XF2011 XF2012 XF2013 XF2014 XF2021 XF2022 XF2023 XF2024 (M2012) 4.16 kV (M2013) 4.16 kV (M2022) 4.16 kV (M2023) 4.16 kV

12 12 12 12 12 12 12 12 1200 TON 1200 TON CHILLER CHILLER XF3022 XF3024 XF3031 XF3033 XF3041 XF3043 PACKAGE A XF3032 XF3034 XF3042 XF3044 XF3051 XF3053 CIRCULATING XF3082 XF3084 XF3091 XF3093 XF3101 XF3103 PACKAGE B XF3092 XF3094 XF3102 XF3104 XF3111 XF3113 CIRCULATING WATER PUMP WATER PUMP B MOTOR B MODULE 2 MODULE 3 MODULE 4 XF3005 MODULE 3 MODULE 4 MODULE 5 MODULE 8 MODULE 9 MODULE 10 MODULE 9 MODULE 10 MODULE 11 SITE COOLING SITE COOLING WATER PUMP TO WATER PUMP XF3006 XF3007 XF3008 MOTOR A 0A-BUS-L-3005 MOTOR C TO TO TO 0A-BUS-L-3006 0B-BUS-L-3007 0B-BUS-L-3008 (M2011) 4.16 kV (M2014) 4.16 kV (M2021) 4.16 kV (M2024) 4.16 kV

12 12 12 12 12 12 12 12 12 12 XF3011 XF3013 XF3021 XF3023 XF3001 XF3062 XF3064 XF3052 XF3054 XF3061 XF3063 XF3002 XF3012 XF3014 XF3071 XF3073 XF3081 XF3083 XF3003 XF3122 XF3124 XF3112 XF3114 XF3121 XF3123 XF3004 XF3072 XF3074 CIRCULATING C WATER PUMP A MODULE 1 MODULE 2 MODULE 6 MODULE 5 MODULE 6 MODULE 1 TO BUS 2011 B MODULE 7 MODULE 8 MODULE 12 MODULE 11 MODULE 12 MODULE 7 B TO TO TO BUS 2011 TO TO D CIRCULATING CIRCULATING SITE COOLING TO BUS 2021 0A-BUS-L-3001 WATER PUMP 0A-BUS-L-3002 CIRCULATING 0B-BUS-L-3003 WATER 0B-BUS-L-3004 WATER PUMP TO BUS 2021 MOTOR A WATER PUMP D PUMP C MOTOR B MOTOR C C TO BUS 2024 1200 TON TO BUS 2014 CHILLER PACKAGE C Tier 2 8.3-65 Revision 4

NuScale Final Safety Analysis Report Onsite Power Systems Figure 8.3-2a: 13.8kV and Switchyard System NOTES FOR FIGURES 8.3-2a - 8.3-2b

1. THE PLANT SWITCHYARD MAY BE CONNECTED TO A TRANSMISSION GRID, OR A MICROGRID, OR TO BOTH.

2. GENERATOR GROUNDING TO BE DETERMINED BY VENDOR DESIGN.

3. ((INCLUSION OF VOLTAGE REGULATING TRANSFORMERS WILL BE BASED ON COMBINED OPERATING LICENSE GRID ANALYSIS.))

4. REFER TO FIGURE 1.7-1 FOR SYMBOL LEGEND AND GENERAL NOTES.

TO SWITCHYARD TO SWITCHYARD TO SWITCHYARD TO SWITCHYARD NOTE 1 NOTE 1 NOTE 1 NOTE 1 BY OTHERS BY OWNER M M M M FIGURE 8.3-2b 0A MAIN POWER 0A MAIN POWER 0A MAIN POWER 0A MAIN POWER AUXILIARY AC TRANSFORMER 1 TRANSFORMER 2 TRANSFORMER 3 TRANSFORMER 4 POWER SOURCE 0B EHVS BUS 1 345kV - 13.8kV 345kV - 13.8kV 345kV - 13.8kV 345kV - 13.8kV A

MODULE 01 STEAM TURBINE MODULE 02 STEAM TURBINE MODULE 03 STEAM TURBINE MODULE 04 STEAM MODULE 05 STEAM MODULE 06 STEAM TURBINE N.O.

GENERATOR GENERATOR GENERATOR TURBINE GENERATOR TURBINE GENERATOR GENERATOR NOTE 2 NOTE 2 NOTE 2 NOTE 2 NOTE 2 NOTE 2 G B C D E F B C D E F G 0A EHVS SWITCHGEAR 1 0A EHVS 0A EHVS 0A EHVS SWITCHGEAR 2 SWITCHGEAR 3 SWITCHGEAR 4 N.O. N.O. N.O. N.O. N.O. N.O. 0A EHVS N.O.

0A EHVS 0A EHVS 0A EHVS BUS 1 - 13.8kV BUS 2 - 13.8kV BUS 3 - 13.8kV BUS 4 - 13.8kV

((0A VOLTAGE REGULATING TRANSFORMER NOTE 3))

M1 M2 M3 M4 EMVS 0A UAT 1 EMVS 0A UAT 2 EMVS 0A UAT 3 EMVS 0A UAT 4 FIGURE 8.3-3a FIGURE 8.3-3a FIGURE 8.3-3a FIGURE 8.3-3a Tier 2 8.3-66 Revision 4

NuScale Final Safety Analysis Report Onsite Power Systems Figure 8.3-2b: 13.8kV and Switchyard System TO SWITCHYARD TO SWITCHYARD TO SWITCHYARD TO SWITCHYARD NOTE 1 NOTE 1 NOTE 1 NOTE 1 BY OTHERS BY OWNER M M M M 0B MAIN POWER 0B MAIN POWER 0B MAIN POWER 0B MAIN POWER TRANSFORMER 1 TRANSFORMER 2 TRANSFORMER 3 TRANSFORMER 4 345kV - 13.8kV 345kV - 13.8kV 345kV - 13.8kV 345kV - 13.8kV FIGURE 8.3-2a 0A EHVS BUS 1 MODULE 07 STEAM TURBINE MODULE 08 STEAM MODULE 09 STEAM TURBINE MODULE 10 STEAM MODULE 11 STEAM TURBINE MODULE 12 STEAM TURBINE A GENERATOR TURBINE GENERATOR GENERATOR TURBINE GENERATOR GENERATOR GENERATOR NOTE 2 NOTE 2 NOTE 2 NOTE 2 NOTE 2 NOTE 2 M H I J K L H I J K L M 0B EHVS SWITCHGEAR 1 0B EHVS 0B EHVS 0B EHVS SWITCHGEAR 2 SWITCHGEAR 3 SWITCHGEAR 4 N.O. N.O. N.O. N.O. N.O. N.O. 0B EHVS N.O.

0B EHVS 0B EHVS 0B EHVS BUS 1 - 13.8kV BUS 2 - 13.8kV BUS 3 - 13.8kV BUS 4 - 13.8kV

((0B VOLTAGE REGULATING TRANSFORMER NOTE 3))

M5 M6 M7 M8 EMVS 0B UAT 1 EMVS 0B UAT 2 EMVS 0B UAT 3 EMVS 0B UAT 4 FIGURE 8.3-3b FIGURE 8.3-3b FIGURE 8.3-3b FIGURE 8.3-3b Tier 2 8.3-67 Revision 4

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E D D E Tier 2 8.3-89 Revision 4

NuScale Final Safety Analysis Report Onsite Power Systems Figure 8.3-4u: Low Voltage Alternating Current Electrical Distribution System

),*85(E ),*85(E

%(096%86 %(096%86

/ /

02'8/( 02'8/(

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%  %

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),*85( ),*85( ),*85( ),*85(

D E E D Tier 2 8.3-90 Revision 4

NuScale Final Safety Analysis Report Onsite Power Systems Figure 8.3-4v: Low Voltage Alternating Current Electrical Distribution System

),*85(E ),*85(E

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/ /

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E D D E Tier 2 8.3-91 Revision 4

NuScale Final Safety Analysis Report Onsite Power Systems Figure 8.3-4w: Low Voltage Alternating Current Electrical Distribution System

),*85(E ),*85(E

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),*85( ),*85( ),*85( ),*85(

D E E D Tier 2 8.3-92 Revision 4

NuScale Final Safety Analysis Report Onsite Power Systems Figure 8.3-4x: Low Voltage Alternating Current Electrical Distribution System

),*85(E ),*85(E

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E D D E Tier 2 8.3-93 Revision 4

NuScale Final Safety Analysis Report Onsite Power Systems Figure 8.3-4y: Low Voltage Alternating Current Electrical Distribution System

),*85(D ),*85(D ),*85(D ),*85(D (096%86 (096%86 (096%86 (096%86

/$ /$ /$ /$

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72:(5 72:(5 72:(5 72:(5 72:(5 72:(5 72:(5 72:(5 72:(5 72:(5 72:(5 72:(5 72:(5 72:(5

)$1 )$1 )$1 )$1 )$1 )$1 )$1 )$1 )$1 )$1 )$1 )$1 )$1 )$1

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),*85(H

),*85(H Tier 2 8.3-94 Revision 4

NuScale Final Safety Analysis Report Onsite Power Systems Figure 8.3-4z: Low Voltage Alternating Current Electrical Distribution System

),*85(E ),*85(E ),*85(E ),*85(E (096%86 (096%86 (096%86 (096%86

/% /% /% /%

% % % %

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N99 N99 N99 N99

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72:(5 72:(5 72:(5 72:(5 72:(5 72:(5 72:(5 72:(5 72:(5 72:(5 72:(5 72:(5 72:(5 72:(5

)$1 )$1 )$1 )$1 )$1 )$1 )$1 )$1 )$1 )$1 )$1 )$1 )$1 )$1

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9 9 1 1

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),*85(H

),*85(H Tier 2 8.3-95 Revision 4

NuScale Final Safety Analysis Report Onsite Power Systems Figure 8.3-5a: Backup Power Supply System 127(6)25),*85(6DE

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02'8/( 02'8/( 02'8/( 02'8/( 02'8/( 02'8/( 02'8/( 02'8/( 02'8/( 02'8/( 02'8/( 02'8/( 02'8/( 02'8/(

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NuScale Final Safety Analysis Report Onsite Power Systems Figure 8.3-5b: Backup Power Supply System

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02'8/( 02'8/( 02'8/( 02'8/( 02'8/( 02'8/( 02'8/( 02'8/( 02'8/( 02'8/( 02'8/( 02'8/( 02'8/( 02'8/(

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0&& 6 0&& 6 0&& 6 0&& 6 0&& 6 0&& 6 &5%0&& &5%0&& 0&& 6 0&& 6 0&& 6 0&& 6 0&& 6 0&& 6

),*85(E ),*85(G ),*85(I ),*85(K ),*85(M ),*85(O ),*85(O ),*85(Q ),*85(Q ),*85(S ),*85(U ),*85(W ),*85(Y ),*85([

Tier 2 8.3-97 Revision 4

NuScale Final Safety Analysis Report Onsite Power Systems Figure 8.3-6: Highly Reliable Direct Current Power System (Common)

NOTES FOR FIGURE 8.3-6:

1. EDSS-C EQUIPMENT IS LOCATED IN THE CRB.

2. REFER TO FIGURE 1.7-1 FOR SYMBOL LEGEND AND GENERAL NOTES.

PLANT DIVISION I PLANT PLANT DIVISION II PLANT EDSS-C DIVISION I EDSS-C DIVISION II BATTERY 1 EDSS-C BATTERY 1 EDSS-C FIGURE 8.3-4k FIGURE 8.3-4n BATTERY 2 FIGURE 8.3-4m FIGURE 8.3-4l BATTERY 2 125VDC 125VDC DIVISION I DIVISION II 60 CELL 125VDC 60 CELL 125VDC 72 HR VRLA MODULE 07 60 CELL 72 HR VRLA MODULE 06 60 CELL MODULE 06 BDG-BACKED BDG-BACKED 72 HR VRLA MODULE 07 BDG-BACKED BDG-BACKED 72 HR VRLA CRB MCC 1 CRB MCC 2 CRB MCC 1 CRB MCC 2 DC1 DC2 DC3 DC4 PLANT BATTERY TEST BATTERY TEST PLANT PLANT BATTERY TEST BATTERY TEST PLANT DIVISION I TERMINAL TERMINAL DIVISION I DIVISION II TERMINAL TERMINAL DIVISION II EDSS-C EDSS-C EDSS-C EDSS-C FUSED FUSED FUSED FUSED TRANSFER PLANT DIVISION I PLANT DIVISION I TRANSFER TRANSFER PLANT DIVISION II PLANT DIVISION II TRANSFER SWITCH 1 EDSS-C EDSS-C SWITCH 2 SWITCH 1 EDSS-C EDSS-C SWITCH 2 BATTERY CHARGER 1 BATTERY CHARGER 2 BATTERY CHARGER 1 BATTERY CHARGER 2 480VAC, 3 INPUT 480VAC, 3 INPUT 480VAC, 3 INPUT 480VAC, 3 INPUT TEST / 125VDC OUTPUT 125VDC OUTPUT TEST / TEST / 125VDC OUTPUT 125VDC OUTPUT TEST /

OFFLINE N.O. N.O. OFFLINE OFFLINE N.O. N.O. OFFLINE RECHARGE RECHARGE RECHARGE RECHARGE NORMAL OFF OFF NORMAL NORMAL OFF OFF NORMAL PLANT DIVISION I EDSS-C SWITCHGEAR PLANT DIVISION II EDSS-C SWITCHGEAR PLANT DIVISION I EDSS-C BUS - 125VDC PLANT DIVISION II EDSS-C BUS - 125VDC DIVISION I PPS DIVISION I PLANT MCR SDIS PLANT MCR SDIS REACTOR POOL AREA EMERGENCY MAIN CRVS AIR-DUCT DIVISION II DIVISION II PLANT MCR SDIS PLANT MCR SDIS REACTOR POOL AREA EMERGENCY MAIN CRVS AIR-DUCT CABINET SDIS CABINET (COMMON) (MODULE SPECIFIC) RAD MONITORS CONTROL ROOM RAD MONITOR PPS CABINET SDIS CABINET (COMMON) (MODULE SPECIFIC) RAD MONITORS CONTROL ROOM RAD MONITOR LIGHTS LIGHTS Tier 2 8.3-98 Revision 4

NuScale Final Safety Analysis Report Onsite Power Systems Figure 8.3-7a: Highly Reliable Direct Current Power System (Module Specific)

NOTES FOR FIGURES 8.3-7a,b:

TABLE A - FIGURE 8.3-4 TABLE B - FIGURE 8.3-4 1. THIS DRAWING IS TYPICAL FOR ALL 12 MODULES: REPLACE "zz" IN ALL INSTANCES WITH MODULE NUMBER FOR THAT REFERENCED SHEETS 1 REFERENCED SHEETS 2 SPECIFIC MODULE'S EDSS-MS ARRANGEMENT.

2. MPS PROVIDES CLASS 1E ELECTRICAL ISOLATION OF SAFETY-RELATED LOADS FROM THE NONSAFETY-RELATED EDSS-MS.

MODULE SHEET MODULE SHEET MODULE SHEET MODULE SHEET 3. SPECIFIC VENDOR-SUPPLIED POWER SOURCE REQUIRED FOR UNIQUE SENSORS NOT POWERED VIA MPS OR NMS.

01 a 07 m 01 b 07 n 4. REFER TO TABLE A FOR FIGURE 8.3-4 SHEETS REFERENCED BY SPECIFIC MODULES' EDSS-MS BATTERY CHARGER 1 CONNECTIONS.

02 c 08 o 02 d 08 p

5. REFER TO TABLE B FOR FIGURE 8.3-4 SHEETS REFERENCED BY SPECIFIC MODULES' EDSS-MS BATTERY CHARGER 2 03 e 09 q 03 f 09 r CONNECTIONS.

04 g 10 s 04 h 10 t 6. REFER TO FIGURE 1.7-1 FOR SYMBOL LEGEND AND GENERAL NOTES.

05 i 11 u 05 j 11 v 06 k 12 w 06 l 12 x MODULE zz CH A MODULE zz CH A MODULE zz CH C MODULE zz CH C DIVISION I - CHANNEL A DIVISION I - CHANNEL C EDSS-MS EDSS-MS EDSS-MS EDSS-MS FIGURE 8.3-4 FIGURE 8.3-4 FIGURE 8.3-4 FIGURE 8.3-4 BATTERY 1 BATTERY 2 BATTERY 1 BATTERY 2 NOTE 4 NOTE 5 NOTE 4 NOTE 5 125VDC 125VDC 125VDC 125VDC 60 CELL 60 CELL 60 CELL 60 CELL 24 HR VRLA MODULE zz MODULE zz 24 HR VRLA 72 HR VRLA MODULE zz MODULE zz 72 HR VRLA BDG-BACKED BDG-BACKED BDG-BACKED BDG-BACKED RXB MCC 1 RXB MCC 4 RXB MCC 2 RXB MCC 3 Dzz1 Dzz2 Dzz5 Dzz6 MODULE BATTERY TEST BATTERY TEST MODULE MODULE BATTERY TEST BATTERY TEST MODULE zz zz CH A TERMINAL TERMINAL zz CH A zz CH C TERMINAL TERMINAL CH C EDSS-MS EDSS-MS EDS-MS EDSS-MS FUSED FUSED FUSED FUSED TRANSFER MODULE zz CH A MODULE zz CH A TRANSFER TRANSFER MODULE zz CH C MODULE zz CH C TRANSFER SWITCH 1 EDSS-MS EDSS-MS SWITCH 2 SWITCH 1 EDSS-MS EDSS-MS SWITCH 2 BATTERY CHARGER 1 BATTERY CHARGER 2 BATTERY CHARGER 1 BATTERY CHARGER 2 480VAC, 3 INPUT 480VAC, 3 INPUT 480VAC, 3 INPUT 480VAC, 3 INPUT TEST / 125VDC OUTPUT 125VDC OUTPUT TEST / TEST / 125VDC OUTPUT 125VDC OUTPUT TEST /

OFFLINE N.O. N.O. OFFLINE OFFLINE N.O. N.O. OFFLINE RECHARGE RECHARGE RECHARGE RECHARGE NORMAL OFF M M OFF NORMAL NORMAL OFF M M OFF NORMAL MODULE zz CH A EDSS-MS SWITCHGEAR MODULE zz CH C EDSS-MS SWITCHGEAR MODULE zz CH A EDSS-MS BUS - 125VDC MODULE zz CH C EDSS-MS BUS - 125VDC CLASS 1E NOTE 2 CLASS 1E NOTE 2 MPS 'A' MPS 'I' MPS 'I' NMS NON-LOOP- NON-LOOP- MPS 'C' MPS 'I' MPS 'I' NMS NON-LOOP- NON-LOOP- BIOSHIELD SC/TD RTS/ESFAS GATEWAY POWERED POWERED SC/TD RTS/ESFAS GATEWAY POWERED POWERED RAD SENSORS SENSORS SENSORS SENSORS MONITOR NOTE 3 NOTE 3 NOTE 3 NOTE 3 Tier 2 8.3-99 Revision 4

NuScale Final Safety Analysis Report Onsite Power Systems Figure 8.3-7b: Highly Reliable Direct Current Power System (Module Specific)

MODULE zz CH B MODULE zz CH MODULE zz CH D MODULE zz CH D DIVISION II - CHANNEL B DIVISION II - CHANNEL D EDSS-MS B EDS-MS EDSS-MS EDSS-MS FIGURE 8.3-4 FIGURE 8.3-4 FIGURE 8.3-4 FIGURE 8.3-4 BATTERY 1 BATTERY 2 BATTERY 1 BATTERY 2 NOTE 4 NOTE 5 NOTE 4 NOTE 5 125VDC 125VDC 125VDC 125VDC 60 CELL 60 CELL 60 CELL 60 CELL 72 HR VRLA MODULE zz MODULE zz 72 HR VRLA 24 HR VRLA MODULE zz MODULE zz 24 HR VRLA BDG-BACKED BDG-BACKED BDG-BACKED BDG-BACKED RXB MCC 2 RXB MCC 3 RXB MCC 1 RXB MCC 4 Dzz3 Dzz4 Dzz7 Dzz8 MODULE BATTERY TEST BATTERY TEST MODULE MODULE BATTERY TEST BATTERY TEST MODULE zz CH B TERMINAL TERMINAL zz CH B zz CH D TERMINAL TERMINAL zz CH D EDSS-MS EDSS-MS EDSS-MS EDSS-MS FUSED FUSED FUSED FUSED TRANSFER MODULE zz CH B MODULE zz CH B TRANSFER TRANSFER MODULE zz CH D MODULE zz CH D TRANSFER SWITCH 1 EDSS-MS EDSS-MS SWITCH 2 SWITCH 1 EDSS-MS EDSS-MS SWITCH 2 BATTERY CHARGER 1 BATTERY CHARGER 2 BATTERY CHARGER 1 BATTERY CHARGER 2 480VAC, 3 INPUT 480VAC, 3 INPUT 480VAC, 3 INPUT 480VAC, 3 INPUT TEST / 125VDC OUTPUT 125VDC OUTPUT TEST / TEST / 125VDC OUTPUT 125VDC OUTPUT TEST /

OFFLINE N.O. N.O. OFFLINE OFFLINE N.O. N.O. OFFLINE RECHARGE RECHARGE RECHARGE RECHARGE NORMAL OFF M M OFF NORMAL NORMAL OFF M M OFF NORMAL MODULE zz CH B EDSS-MS SWITCHGEAR MODULE zz CH D EDSS-MS SWITCHGEAR MODULE zz CH B EDSS-MS BUS - 125VDC MODULE zz CH D EDSS-MS BUS - 125VDC CLASS 1E NOTE 2 CLASS 1E NOTE 2 MPS 'B' MPS 'II' MPS 'II' NMS NON-LOOP- NON-LOOP- BIOSHIELD MPS 'D' MPS 'II' MPS 'II' NMS NON-LOOP- NON-LOOP-SC/TD RTS/ESFAS GATEWAY POWERED POWERED RAD SC/TD RTS/ESFAS GATEWAY POWERED POWERED SENSORS SENSORS MONITOR SENSORS SENSORS NOTE 3 NOTE 3 NOTE 3 NOTE 3 Tier 2 8.3-100 Revision 4

NuScale Final Safety Analysis Report Onsite Power Systems Figure 8.3-8a: Normal Direct Current Power System NOTES FOR FIGURES 8.3-8a:

EDNS-RXB FIGURE 8.3-4 FIGURE 8.3-4 1. MANUAL MAINTENANCE BYPASS SWITCH WITH OVERLAPPING CONTACTS PERMITS TRANSFERRING TO ALTERNATE SOURCE BATTERY WITHOUT INTERRUPTION OF POWER AND AT THE SAME TIME ISOLATES THE INVERTER.

250VDC 2. DELETED ELV CONNECTION ELV CONNECTION 120 CELL 3. CLASS 1E CONTROL ROD DRIVE SYSTEM MAIN POWER BREAKERS ARE CONTROLLED BY THE MPS.

NOTE 5 NOTE 5 40 MIN VRLA 4. ENTIRE DRAWING IS TYPICAL FOR THE ENDS-NORTH RXB AND ENDS-SOUTH RXB SUBSYSTEMS.

5. REFER TO TABLE A FOR TABLE OF CONNECTIONS BETWEEN EDNS-RXB SUSYSTEMS AND ELVS.

6. REFER TO FIGURE 1.7-1 FOR SYMBOL LEGEND AND GENERAL NOTES.

EDNS-RXB SPARE BATTERY/ BATTERY TEST FUSED TRANSFER CHARGER TERMINAL TERMINAL SWITCH EDNS-RXB BATTERY CHARGER 480VAC, 3 INPUT TEST / 250VDC OUTPUT TABLE A - EDNS RXB OFFLINE N.O. CONNECTIONS RECHARGE ID SHEET ID SHEET N.O. EDNS-RXB NORTH N011 k NB01 l OFF M EDNS-RXB SOUTH N021 m NB02 n NORMAL EDNS-RXB DC SWITCHGEAR EDNS-RXB DC BUS - 250VDC EDNS-RXB EDNS-RXB EDNS-RXB INVERTER 1 VOLTAGE REGULATING INVERTER 2 TRANSFORMER 250VDC INPUT 250VDC INPUT 120/208VAC, 3 OUTPUT 480V - 120/208VAC, 3 120/208VAC, 3 OUTPUT STATIC SWITCH STATIC SWITCH MANUAL MANUAL MAINTENANCE/BYPASS MAINTENANCE/BYPASS SWITCH (NOTE 1) SWITCH (NOTE 1)

EDNS-RXB AC SWITCHGEAR EDNS-RXB AC BUS - 120/208VAC, 3 MPS CLASS 1E NOTE 3 DIVISION I DIVISION II EDNS-RXB BATTERY BACKED AC LOADS CRDS MAIN POWER Tier 2 8.3-101 Revision 4

NuScale Final Safety Analysis Report Onsite Power Systems Figure 8.3-8b: Normal Direct Current Power System EDNS-TGB NOTES FOR FIGURES 8.3-8b:

FIGURE 8.3-4 FIGURE 8.3-4 BATTERY 1. MANUAL MAINTENANCE BYPASS SWITCH WITH OVERLAPPING CONTACTS PERMITS TRANSFERRING TO ALTERNATE SOURCE 250VDC WITHOUT INTERRUPTION OF POWER AND AT THE SAME TIME ISOLATES THE INVERTER.

ELVS CONNECTION ELVS CONNECTION 2. DELETED 120 CELL NOTE 4 NOTE 4 3. ENTIRE DRAWING IS TYPICAL FOR THE ENDS-NORTH TGB AND ENDS-SOUTH TGB SUBSYSTEMS.

40 MIN VRLA

4. REFER TO TABLE A FOR CONNECTIONS BETWEEN EDNS-TGB SUBSYSTEMS AND ELVS.

5. REFER TO TABLE B FOR MODULE NUMBER OF EACH STG EMERGENCY DC LUBE OIL PUMP MOTOR.

6. REFER TO FIGURE 1.7-1 FOR SYMBOL LEGEND AND GENERAL NOTES.

EDNS-TGB SPARE BATTERY/ BATTERY TEST EDNS-TGB FUSED TRANSFER CHARGER TERMINAL TERMINAL BATTERY CHARGER SWITCH 480VAC, 3 INPUT TEST / 250VDC OUTPUT OFFLINE N.O.

RECHARGE TABLE A - EDNS TGB N.O. CONNECTIONS OFF M ID SHEET ID SHEET NORMAL EDNS-TGB NORTH N011 k NB01 l EDNS-TGB SOUTH N021 m NB02 n EDNS-TGB DC SWITCH GEAR EDNS-TGB DC BUS - 250VDC EDNS-TGB EDNS-TGB INVERTER VOLTAGE REGULATING STG TURBINE STG TURBINE STG TURBINE STG TURBINE STG TURBINE STG TURBINE TRANSFORMER EMERGENCY EMERGENCY EMERGENCY EMERGENCY EMERGENCY EMERGENCY 250VDC INPUT DC LUBE OIL DC LUBE OIL DC LUBE OIL DC LUBE OIL DC LUBE OIL DC LUBE OIL 120/208VAC, 3 OUTPUT 480V - 120/208VAC, 3 PUMP MOTOR PUMP MOTOR PUMP MOTOR PUMP MOTOR PUMP MOTOR PUMP MOTOR NOTE 5 NOTE 5 NOTE 5 NOTE 5 NOTE 5 NOTE 5 STATIC SWITCH TABLE B - STG MODULE NUMBER EDNS-TGB NORTH 01 02 03 04 05 06 MANUAL EDNS-TGB SOUTH 07 08 09 10 11 12 MAINTENANCE/BYPASS SWITCH (NOTE 1)

EDNS-TGB AC SWITCH GEAR EDNS-TGB AC BUS - 120/208VAC, 3 EDNS-TGB BATTERY BACKED AC LOADS Tier 2 8.3-102 Revision 4

NuScale Final Safety Analysis Report Onsite Power Systems Figure 8.3-8c: Normal Direct Current Power System EDNS-CRB NOTES FOR FIGURES 8.3-8c:

FIGURE 8.3-4k FIGURE 8.3-4n BATTERY 1. MANUAL MAINTENANCE BYPASS SWITCH WITH OVERLAPPING CONTACTS PERMITS TRANSFERRING TO 125VDC ALTERNATE SOURCE WITHOUT INTERRUPTION OF POWER AND AT THE SAME TIME ISOLATES THE INVERTER.

MODULE 06 BUS 1 MODULE 07 BDG- 2. DELETED 60 CELL CRB MCC BACKED CRB MCC 2 3. REFER TO FIGURE 1.7-1 FOR SYMBOL LEGEND AND GENERAL NOTES.

40 MIN VRLA N051 NB05 EDNS-CRB SPARE BATTERY/ BATTERY TEST FUSED TRANSFER CHARGER TERMINAL TERMINAL SWITCH EDNS-CRB BATTERY CHARGER 480VAC, 3 INPUT TEST / 125VDC OUTPUT OFFLINE N.O.

RECHARGE N.O.

OFF M NORMAL EDNS-CRB DC SWITCHGEAR EDNS-CRB DC BUS - 125VDC EDNS-CRB EDNS-CRB INVERTER VOLTAGE REGULATING TRANSFORMER 125VDC INPUT 120/208VAC, 3 OUTPUT 480V - 120/208VAC, 3 STATIC SWITCH MANUAL MAINTENANCE/BYPASS SWITCH (NOTE 1)

EDNS-CRB AC SWITCHGEAR EDNS-CRB AC BUS - 120/208VAC, 3 EDNS-CRB BATTERY BACKED AC LOADS Tier 2 8.3-103 Revision 4

NuScale Final Safety Analysis Report Onsite Power Systems Figure 8.3-8d: Normal Direct Current Power System EDNS-RWB NOTES FOR FIGURES 8.3-8d:

FIGURE 8.3-4u FIGURE 8.3-4b BATTERY 1. MANUAL MAINTENANCE BYPASS SWITCH WITH OVERLAPPING CONTACTS PERMITS TRANSFERRING TO 125VDC ALTERNATE SOURCE WITHOUT INTERRUPTION OF POWER AND AT THE SAME TIME ISOLATES THE INVERTER.

MODULE 11 BUS 1 MODULE 01 BDG- 2. DELETED 60 CELL RWB MCC BACKED RXB MCC 4 3. REFER TO FIGURE 1.7-1 FOR SYMBOL LEGEND AND GENERAL NOTES.

40 MIN VRLA N061 NB06 EDNS-RWB SPARE BATTERY/ BATTERY TEST FUSED TRANSFER CHARGER TERMINAL TERMINAL SWITCH EDNS-RWB BATTERY CHARGER 480VAC, 3 INPUT TEST / 125VDC OUTPUT OFFLINE N.O.

RECHARGE N.O.

OFF M NORMAL EDNS-RWB DC SWITCHGEAR EDNS-CRB DC BUS - 125VDC EDNS-RWB EDNS-RWB INVERTER VOLTAGE REGULATING TRANSFORMER 125VDC INPUT 120/208VAC, 3 OUTPUT 480V - 120/208VAC, 3 STATIC SWITCH MANUAL MAINTENANCE/BYPASS SWITCH (NOTE 1)

EDNS-RWB AC SWITCHGEAR EDNS-RWB AC BUS - 120/208VAC, 3 EDNS-RWB BATTERY BACKED AC LOADS Tier 2 8.3-104 Revision 4

NuScale Final Safety Analysis Report Onsite Power Systems Figure 8.3-8e: Normal Direct Current Power System NOTES FOR FIGURES 8.3-8e:

1. DELETED

2. ENTIRE DRAWING IS TYPICAL FOR THE ENDS-PDC 60 CELLS SUBSYSTEMS.

3. REFER TO TABLE A FOR CONNECTIONS BETWEEN EDNS-PDC SUBSYSTEMS AND ELVS.

4. REFER TO FIGURE 1.7-1 FOR SYMBOL LEGEND AND GENERAL NOTES.

EDNS-PDC BATTERY 125VDC FIGURE 8.3-4 FIGURE 8.3-4 60 CELL 40 MIN VRLA ELVS CONNECTION ELVS CONNECTION NOTE 2 NOTE 2 EDNS-PDC FUSED BATTERY TEST TRANSFER TERMINAL SWITCH TABLE A - EDNS-PDC EDNS-PDC EDNS-PDC CONNECTIONS BATTERY SPARE BATTERY ID SHEET ID SHEET CHARGER CHARGER EDNS-PDC #3 N091 g N092 h EDNS-PDC #4 N121 s N122 t EDNS-PDC #5 N131 q N132 r 480VAC, 3 INPUT 480VAC, 3 INPUT 125VDC OUTPUT 125VDC OUTPUT EDNS-PDC #6 N141 q N142 r TEST /

OFFLINE EDNS-PDC #7 N071 y N072 y N.O. N.O.

RECHARGE EDNS-PDC #8 N081 z N082 z NORMAL OFF M M EDNS-PDC DC SWITCHGEAR N.O.

EDNS-PDC DC BUS - 125VDC EDNS-PDC BATTERY BACKED DC LOADS Tier 2 8.3-105 Revision 4

NuScale Final Safety Analysis Report Onsite Power Systems Figure 8.3-8f: Normal Direct Current Power System NOTES FOR FIGURES 8.3-8f:

1. DELETED

2. ENTIRE DRAWING IS TYPICAL FOR THE ENDS-PDC 120 CELL SUBSYSTEMS.

3. REFER TO TABLE A FOR CONNECTIONS BETWEEN EDNS-PDC 120 CELL SUBSYSTEMS AND ELVS.

4. REFER TO FIGURE 1.7-1 FOR SYMBOL LEGEND AND GENERAL NOTES.

EDNS-PDC #1 BATTERY 125VDC 120 CELL FIGURE 8.3-4e FIGURE 8.3-4f 40 MIN VRLA MODULE 03 BUS 1 TGB MODULE 03 BUS 3 TGB MCC MCC N101 N102 EDNS-PDC #1 BATTERY TEST FUSED TERMINAL TRANSFER SWITCH TABLE A - EDNS-PDC EDNS-PDC #1 EDNS-PDC #1 CONNECTIONS BATTERY SPARE BATTERY CHARGER CHARGER ID SHEET ID SHEET EDNS-PDC #1 N101 e N102 f EDNS-PDC #2 N111 g N112 h 480VAC, 3 INPUT 480VAC, 3 INPUT TEST / 125VDC OUTPUT 125VDC OUTPUT OFFLINE N.O. N.O.

RECHARGE NORMAL OFF M M EDNS-PDC #1 DC SWITCHGEAR N.O.

EDNS-PDC #1 DC BUS - 125VDC EDNS-PDC 120 CELL BATTERY BACKED DC LOADS Tier 2 8.3-106 Revision 4

A station blackout (SBO) is a complete loss of offsite and onsite alternating current (AC) power concurrent with a turbine trip and the unavailability of onsite emergency AC power. The SBO rule, 10 CFR 50.63, requires each plant to demonstrate sufficient capacity and capability to ensure that the reactor core is cooled and appropriate containment integrity is maintained in the event of an SBO for the specified duration. As described in Section 8.3, the NuScale Power Module (NPM) design does not rely on the use of onsite or offsite AC power for the performance of safety-related functions during a design basis event. As a result, emergency onsite AC power is not included in the design.

The SBO duration for passive plant designs is 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />, which is consistent with Nuclear Regulatory Commission policy provided by SECY-94-084 and SECY-95-132 and the associated staff requirements memorandums. Passive plants are required to demonstrate that safety-related functions can be performed without reliance on AC power for 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> after the initiating event. The relevant guidelines of Regulatory Guide (RG) 1.155 are applied as they pertain to compliance with 10 CFR 50.63 for the passive NuScale design.

1 Station Blackout Analysis Assumptions The analysis of the SBO transient response includes the following assumptions:

• A total of 12 NPMs and supporting equipment are initially operating normally at a minimum of 100 percent rated thermal power for 100 days.

• At time zero, an SBO occurs as a result of a complete loss of onsite and offsite AC power.

• The 12 NPM turbine generators trip as a result of the loss of AC power.

• Power from the highly reliable DC power system (EDSS) is available.

• No credit is taken for manual operator actions.

• No additional single failures occur.

• The event duration is 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />.

2 Station Blackout Analysis and Results The SBO does not pose a significant challenge to the advanced passive design of the NuScale Power Plant, which does not rely on AC power for performing safety functions. A safe and stable shutdown is automatically achieved and maintained for 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> without operator actions. The SBO transient analysis demonstrates that the acceptance criteria of 10 CFR 50.63 are met.

The SBO transient analysis employs the NRELAP5 code to model the NPM response to an SBO event for the required 72-hour duration. The NRELAP5 model, which is described in Section 15.0, is qualified to predict the plant response to the SBO. The core decay heat model is based on an infinite operating time at an initial power of 100 percent, and the analysis conservatively accounts for the combined heat input from a total of 12 NPMs and the spent fuel pool on the reactor pool response.

2 8.4-1 Revision 4

results in a module protection system (MPS) reactor trip signal on high pressurizer pressure, a decay heat removal system (DHRS) actuation, and a single cycle of a reactor safety valve (RSV). Within 65 seconds, the MPS initiates automatic containment isolation on a low AC voltage to battery charger signal. The containment isolation includes the chemical and volume control system valves, which prevents inventory loss due to letdown.

Within one minute, the DHRS begins to transfer heat from the reactor to the reactor pool and continues to operate for the event duration. After 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, the MPS actuates the emergency core cooling system (ECCS), and the ECCS vent and recirculation valves automatically open. At this point, the pressure and water level in the reactor pressure vessel (RPV) decrease, and containment vessel (CNV) pressure rapidly increases until equilibrium is reached. The DHRS cooling then declines in favor of cooling through the CNV wall via reactor coolant that circulates through the CNV. Stable cooling continues to the end of the transient, with a continued slow decrease in the temperature and pressure in the RPV and CNV. The water level in the RPV remains stable at more than 9 feet above the top of the active fuel.

The analysis results show that a safe and stable shutdown is achieved, and that the reactor is cooled and containment integrity is maintained for the 72-hour duration without reliance on operator actions. The core remains subcritical for the duration of the event. The reactor coolant inventory ensures that the core remains covered without the need for makeup systems. The RPV water level is well above the top of active fuel as shown in Figure 8.4-1. After the reactor trips, the RPV pressure decreases rapidly and stabilizes at low pressures as shown in Figure 8.4-2. In addition, containment pressure and temperature are well below the design limits of 1000 psia and 550 degrees F as shown in Figure 8.4-3 and Figure 8.4-4.

3 Station Blackout Coping Equipment Assessment The design adequacy and capability of equipment needed to cope with an SBO for the 72-hour duration of the event was evaluated, and the applicable guidance of Section C.3.2 of RG 1.155 was considered. The evaluation provides reasonable assurance that the required SBO equipment remains operable, and that special equipment provisions or operator actions are not necessary to ensure the operability of SBO mitigation equipment for the 72-hour duration. Nonsafety-related equipment is not relied upon to mitigate an SBO, and there is no SBO mitigation equipment that requires regulatory oversight under the regulatory treatment of nonsafety systems process, which is described in Section 8.1.4.3 and Section 19.3.

Consistent with the 10 CFR 50.2 definition of an SBO, the SBO transient analysis assumes a complete loss of AC power and that the EDSS remains operable during the transient. The EDSS batteries have sufficient capacity to provide power to post-accident monitoring and main control room emergency lighting loads for the 72-hour duration without charging.

The EDSS design description, which includes testing and design criteria, is provided in Section 8.3.2.

Although not required to meet the requirements of 10 CFR 50.63, an SBO transient sensitivity case that considered a simultaneous complete loss of AC and DC power was also 2 8.4-2 Revision 4

containment integrity are met under conditions that exceed those required to demonstrate compliance with the rule.

The environmental conditions in the main control room during the SBO were evaluated.

The control room remains habitable for the duration of the SBO event using the control room habitability system. The control room instrumentation to monitor the event mitigation and confirm the status of reactor cooling, reactor integrity, and containment integrity also remains available. The control room habitability system is described in Section 6.4.

Appropriate containment integrity is provided during the SBO event. The SBO transient analysis containment response demonstrates that the containment temperature and pressure are within design limits. The containment isolation valves automatically close following receipt of an MPS actuation signal. Containment isolation valve position indication is powered from the EDSS and is available for the operators to verify valve closure.

4 Station Blackout Procedures and Training The SBO procedures and training consider the relevant guidance of RG 1.155 as it pertains to passive plants. Training and procedures to mitigate an SBO event are implemented in accordance with Section 13.2 and Section 13.5. The SBO mitigation procedures address SBO response (e.g. restoration of onsite standby power sources), AC power restoration (e.g.

coordination with transmission system load dispatcher), and severe weather guidance (e.g.

identification of site-specific actions to prepare for the onset of severe weather such as an impending tornado), as applicable. Restoration from an SBO event will be contingent upon AC power being made available from the offsite power system (if provided) or the backup power supply system, which are described in Section 8.2 and Section 8.3.

2 8.4-3 Revision 4

Station Blackout Event Time (Seconds) Value of AC power 0 h pressurizer pressure signal 9 2000 psia actuation signal 9 actuation 11 imum primary pressure 16 2081 psia S valves fully open 41 imum secondary pressure 52 1247 psia tainment isolation signal 60 tainment isolation 62 S actuation signal 86400 S actuation 86403 imum containment temperature 86545 252 °F imum containment pressure 86648 36 psia 2 8.4-4 Revision 4

cale Final Safety Analysis Report 40 35 RPV water level above TAF (ft) 30 25 20 15 10 5

0 10 20 30 40 50 60 70 Time (hr)

Station Blackout

cale Final Safety Analysis Report 2500 2000 RPV pressure (psia) 1500 1000 500 0

0 10 20 30 40 50 60 70 Time (hr)

Station Blackout

cale Final Safety Analysis Report 40 35 30 CNV pressure (psia) 25 20 15 10 5

0 0 10 20 30 40 50 60 70 Time (hr)

Station Blackout

cale Final Safety Analysis Report Figure 8.4-4: Station Blackout Containment Vessel Temperature 255 250 245 240 CNV temperature (ºF) 235 230 225 220 215 210 205 200 0 10 20 30 40 50 60 70 Time (hr)

Station Blackout