Text

Issuance of Amendment No. 203 Adopt TSTF-582, Revision 0, Reactor Pressure Vessel Water Inventory Control (RPV WIC) Enhancements
	ML20339A518
Person / Time
Site:	River Bend
Issue date:	01/06/2021
From:	Perry Buckberg; Plant Licensing Branch IV
To:	; Entergy Operations
	Buckberg P
References
	EPID L-2020-LLA-0204
	Download: ML20339A518 (24)
	v • d • e

January 6, 2021 Vice President, Operations Entergy Operations, Inc.

River Bend Station 5485 US Highway 61 St. Francisville, LA 70775

SUBJECT:

RIVER BEND STATION, UNIT 1 - ISSUANCE OF AMENDMENT NO. 203 RE: TO REVISE TECHNICAL SPECIFICATIONS TO ADOPT TECHNICAL SPECIFICATIONS TASK FORCE TRAVELER TSTF-582, REVISION 0, RPV WIC ENHANCEMENTS (EPID L-2020-LLA-0204)

Dear Sir or Madam:

The U.S. Nuclear Regulatory Commission (NRC, the Commission) has issued the enclosed Amendment No. 203 to Renewed Facility Operating License No. NPF-47 for River Bend Station, Unit 1 (River Bend). The amendment consists of changes to the Technical Specifications (TSs) in response to your application dated September 4, 2020 (Agencywide Documents Access and Management System (ADAMS) Accession No. ML20248H528).

The amendment modifies the River Bend TSs related to reactor pressure vessel (RPV) water inventory control (WIC) based on Technical Specifications Task Force (TSTF) Traveler TSTF-582, Revision 0, RPV WIC Enhancements, which was approved by the NRC on August 13, 2020, for adoption into the River Bend TSs.

A copy of the related safety evaluation is also enclosed. Notice of Issuance will be included in the Commissions monthly Federal Register notice.

Sincerely,

/RA/

Perry H. Buckberg, Senior Project Manager Plant Licensing Branch IV Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Docket No. 50-458

Enclosures:

1. Amendment No. 203 to NPF-47

2. Safety Evaluation cc: Listserv

ENTERGY LOUISIANA, LLC AND ENTERGY OPERATIONS, INC.

DOCKET NO. 50-458 RIVER BEND STATION, UNIT 1 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 203 Renewed License No. NPF-47

1. The Nuclear Regulatory Commission (the Commission) has found that:

A. The application for amendment by Entergy Operations, Inc. (the licensee), dated September 4, 2020, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commissions rules and regulations set forth in 10 CFR Chapter I; B. The facility will operate in conformity with the application, as amended, the provisions of the Act, and the rules and regulations of the Commission; C. There is reasonable assurance (i) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commissions regulations; D. The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E. The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commissions regulations and all applicable requirements have been satisfied.

Enclosure 1

2. Accordingly, the license is amended by changes to the Technical Specifications as indicated in the attachment to this license amendment, and paragraph 2.C.(2) of Renewed Facility Operating License No. NPF-47 is hereby amended to read as follows:

(2) Technical Specifications and Environmental Protection Plan The Technical Specifications contained in Appendix A, as revised through Amendment No. 203 and the Environmental Protection Plan contained in Appendix B, are hereby incorporated in the renewed license. EOI shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.

3. This amendment is effective as of its date of issuance and shall be implemented within 30 days from the date of issuance.

FOR THE NUCLEAR REGULATORY COMMISSION Digitally signed by Jennifer L. Jennifer L. Dixon-Herrity Date: 2021.01.06 Dixon-Herrity 09:41:44 -05'00' Jennifer L. Dixon-Herrity, Chief Plant Licensing Branch IV Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation

Attachment:

Changes to the Renewed Facility Operating License No. NPF-47 and Technical Specifications Date of Issuance: January 6, 2021

ATTACHMENT TO LICENSE AMENDMENT NO. 203 RENEWED FACILITY OPERATING LICENSE NO. NPF-47 RIVER BEND STATION, UNIT 1 DOCKET NO. 50-458 Replace the following pages of the Renewed Facility Operating License No. NPF-47 and Appendix A Technical Specifications with the attached revised pages. The revised pages are identified by amendment number and contain a marginal line indicating the area of change.

Renewed Facility Operating License REMOVE INSERT Technical Specifications REMOVE INSERT 1.0-2a 1.0-2a 3.3-43a 3.3-43a 3.3-43b 3.3-43b 3.3-43c 3.3-43c 3.3-43d ----

3.3-43e ----

3.3-50 3.3-50 3.3-51 3.3-51 3.3-72 3.3-72 3.5-1 3.5-1 3.5-8 3.5-8 3.5-9 3.5-9 3.8-20 3.8-20

(2) EOI, pursuant to Section 103 of the Act and 10 CFR Part 50, to possess, use and operate the facility at the above designated location in accordance with the procedures and limitations set forth in this renewed license; (3) EOI, pursuant to Section 103 of the Act and 10 CFR Part 70, to receive, possess and to use at any time special nuclear material as reactor fuel, in accordance with the limitations for storage and amounts required for reactor operation, as described in the Final Safety Analysis Report, as supplemented and amended; (4) EOI, pursuant to Section 103 of the Act and 10 CFR Parts 30, 40 and 70, to receive, possess, and use at any time any byproduct, source and special nuclear material as sealed neutron sources for reactor startup, sealed sources for reactor instrumentation and radiation monitoring equipment calibration, and as fission detectors in amounts as required; (5) EOI, pursuant to Section 103 of the Act and 10 CFR Parts 30, 40 and 70, to receive, possess, and use in amounts as required any byproduct, source or special nuclear material without restriction to chemical or physical form, for sample analysis or instrument calibration or associated with radioactive apparatus or components; and (6) EOI, pursuant to Section 103 of the Act and 10 CFR Parts 30, 40 and 70, to possess, but not separate, such byproduct and special nuclear materials as may be produced by the operation of the facility.

C. This renewed license shall be deemed to contain and is subject to the conditions specified in the Commissions regulations set forth in 10 CFR Chapter I and is subject to all applicable provisions of the Act and the rules, regulations and orders of the Commission now or hereafter in effect; and is subject to the additional conditions specified or incorporated below:

(1) Maximum Power Level EOI is authorized to operate the facility at reactor core power levels not in excess of 3091 megawatts thermal (100% rated power) in accordance with the conditions specified herein.

(2) Technical Specifications and Environmental Protection Plan The Technical Specifications contained in Appendix A, as revised through Amendment No. 203 and the Environmental Protection Plan contained in Appendix B, are hereby incorporated in the renewed license. EOI shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.

Amendment No. 203

Definitions 1.1 1.1 Definitions (continued)

DRAIN TIME The DRAIN TIME is the time it would take for the water inventory in and above the Reactor Pressure Vessel (RPV) to drain to the top of the active fuel (TAF) seated in the RPV assuming:

a. The water inventory above the TAF is divided by the limiting drain rate;

b. The limiting drain rate is the larger of the drain rate through a single penetration flow path with the highest flow rate, or the sum of the drain rates through multiple penetration flow paths susceptible to a common mode failure, for all penetration flow paths below the TAF except:

1. Penetration flow paths connected to an intact closed system, or isolated by manual or automatic valves that are closed and administratively controlled in the closed position, blank flanges, or other devices that prevent flow of reactor coolant through the penetration flow paths;

2. Penetration flow paths capable of being isolated by valves that will close automatically without offsite power prior to the RPV water level being equal to the TAF when actuated by RPV water level isolation instrumentation; or

3. Penetration flow paths with isolation devices that can be closed prior to the RPV water level being equal to the TAF by a dedicated operator trained in the task, who is in continuous communication with the control room, is stationed at the controls, and is capable of closing the penetration flow path isolation devices without offsite power.

c. The penetration flow paths required to be evaluated per paragraph b) are assumed to open instantaneously and are not subsequently isolated, and no water is assumed to be subsequently added to the RPV water inventory; (continued)

RIVER BEND 1.0-2a Amendment No. 193, 203

RPV Water Inventory Inventory Control Instrumentation 3.3.5.2 3.3 INSTRUMENTATION 3.3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation LCO 3.3.5.2 The RPV Water Inventory Control instrumentation for each Function in Table 3.3.5.2-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.5.2-1.

ACTIONS

NOTE-----------------------------------------------------------

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Initiate action to place Immediately inoperable. channel in trip.

OR A.2.1 Declare associated Immediately penetration flow path(s) incapable of automatic isolation.

AND A.2.2 Initiate action to calculate Immediately DRAIN TIME.

RIVER BEND 3.3-43a Amendment No. 193, 203

RPV Water Inventory Inventory Control Instrumentation 3.3.5.2 SURVEILLANCE REQUIREMENTS

NOTE------------------------------------------------------------

These SRs apply to each Function in Table 3.3.5.2-1.

SURVEILLANCE FREQUENCY SR 3.3.5.2.1 Perform CHANNEL CHECK. In accordance with the Surveillance Frequency Control Program SR 3.3.5.2.2 Perform CHANNEL FUNCTIONAL TEST. In accordance with the Surveillance Frequency Control Program RIVER BEND 3.3-43b Amendment No. 193, 203

RPV Water Inventory Control Instrumentation 3.3.5.2 Table 3.3.5.2-1 (page 1 of 1)

RPV Water Inventory Control Instrumentation APPLICABLE MODES OR OTHER REQUIRED SPECIFIED CHANNELS PER ALLOWABLE FUNCTION CONDITIONS FUNCTION VALUE

1. RHR System Isolation

a. Reactor Vessel Water Level - Low (a) 2 in one trip > 8.7 inches (Level 3) system

2. Reactor water Cleanup (RWCU) System Isolation

a. Reactor Water Level Low, Low (a) 2 in one trip > -47 inches (Level 2) system (a) When automatic isolation of the associated penetration flow path(s) is credited in calculating DRAIN TIME RIVER BEND 3.3-43c Amendment No. 193, 202, 203

Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME H. As required by Required H.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Action C.1 and referenced in Table 3.3.6.1-1. AND OR H.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months Required Action and associated Completion Time of Condition F or G not met.

I. As required by Required I.1 Declare associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Action C.1 and referenced standby liquid control in Table 3.3.6.1-1. subsystem inoperable.

OR I.2 Isolate the Reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Water Cleanup System.

J. As required by Required J.1 Initiate action to restore Immediately Action C.1 and referenced channel to OPERABLE in Table 3.3.6.1-1. status.

(continued)

RIVER BEND 3.3-50 Amendment No. 81, 203

Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME K. As required by Required K.1 Isolate the affected Immediately Action C.1 and referenced penetration flow path(s).

in Table 3.3.6.1-1.

OR K.2.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND K.2.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months RIVER BEND 3.3-51 Amendment No. 81, 203

LOP Instrumentation 3.3.8.1 3.3 INSTRUMENTATION 3.3.8.1 Loss of Power (LOP) Instrumentation LCO 3.3.8.1 The LOP instrumentation for each Function in Table 3.3.8.1-1 shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3 ACTIONS

NOTE---------------------------------------------------------

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Place channel in trip. 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable.

B. Required Action and B.1 Declare associated DG Immediately associated Completion inoperable.

Time not met.

RIVER BEND 3.3-72 Amendment No. 81, 203

ECCS Operating 3.5.1 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS), RPV WATER INVENTORY CONTROL, AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.1 ECCS -Operating LCO 3.5.1 Each ECCS injection/spray subsystem and the Automatic Depressurization System (ADS) function of seven safety/relief valves shall be OPERABLE.

APPLICABILITY: MODE 1, MODES 2 and 3, except ADS valves are not required to be OPERABLE with reactor steam dome pressure 100 psig.

ACTIONS

NOTE----------------------------------------------------------------

LCO 3.0.4.b is not applicable to High Pressure Core Spray (HPCS).

CONDITION REQUIRED ACTION COMPLETION TIME A. One low pressure ECCS A.1 Restore low pressure 7 days injection/spray subsystem ECCS injection/spray inoperable. subsystem to OPERABLE status.

B. HPCS System inoperable. B.1 Verify by administrative 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months means RCIC System is OPERABLE when RCIC is required to be OPERABLE.

AND B.2 Restore HPCS System 14 days to OPERABLE status.

(continued)

RIVER BEND 3.5-1 Amendment No. 81, 156, 193, 203

RPV Water Inventory Control 3.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify DRAIN TIME is > 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . In accordance with the Surveillance Frequency Control Program SR 3.5.2.2 Verify, for a required low pressure ECCS In accordance with injection/spray subsystem, the suppression pool the Surveillance water level is 13 ft 3 inches. Frequency Control Program SR 3.5.2.3 Verify, for the required High Pressure Core Spray In accordance with (HPCS) System, the: the Surveillance Frequency Control

a. Suppression pool water level is 13 ft 3 inches; Program or

b. Condensate storage tank water level is 11 ft 1 inch.

SR 3.5.2.4 Verify, for the required ECCS injection/spray In accordance with subsystem, locations susceptible to gas the Surveillance accumulation are sufficiently filled with water. Frequency Control Program (continued)

RIVER BEND 3.5-8 Amendment No. 81, 188, 193, 196, 203

RPV Water Inventory Control 3.5.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.2.5 -----------------------------NOTES------------------------------- A

1. Operation may be through the test return line.

2. Credit may be taken for normal system operation to satisfy this SR.

Operate the required ECCS injection/spray In accordance subsystem for > 10 minutes. with the Surveillance Frequency Control Program SR 3.5.2.6 Verify each valve credited for automatically isolating In accordance with a penetration flow path actuates to the isolation the Surveillance position on an actual or simulated actuation signal. Frequency Control Program SR 3.5.2.7 -----------------------------NOTE--------------------------------

Vessel injection/spray may be excluded.

Verify the required ECCS injection/spray subsystem In accordance with can be manually operated. the Surveillance Frequency Control Program RIVER BEND 3.5-9 Amendment No. 81, 168, 193, 196, 203

AC SourcesShutdown 3.8.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.2.1 -----------------------------NOTE-------------------------------

The following SRs are not required to be performed:

SR 3.8.1.3, SR 3.8.1.9, SR 3.8.1.10, SR 3.8.1.14, and SR 3.8.1.16.

The following SRs are applicable for AC sources In accordance with required to be OPERABLE: applicable SRs SR 3.8.1.1 SR 3.8.1.5 SR 3.8.1.14 SR 3.8.1.2 SR 3.8.1.6 SR 3.8.1.16 SR 3.8.1.3 SR 3.8.1.9 SR 3.8.1.4 SR 3.8.1.10 RIVER BEND 3.8-20 Amendment No. 81, 121, 203

SAFETY EVALUATION BY THE OFFICE OF NUCLEAR REACTOR REGULATION RELATED TO AMENDMENT NO. 203 TO RENEWED FACILITY OPERATING LICENSE NO. NPF-47 ENTERGY OPERATIONS, INC.

RIVER BEND STATION, UNIT 1 DOCKET NO. 50-458

1.0 PROPOSED CHANGE

S Entergy Operations, Inc. (Entergy, the licensee) requested changes to the Technical Specifications (TSs) for River Bend Station, Unit 1 (River Bend) by a license amendment request dated September 4, 2020 (Agencywide Documents Access and Management System (ADAMS) Accession No. ML20248H528). The licensee requested that the U.S. Nuclear Regulatory Commission (NRC, the Commission) process the proposed license amendment request under the consolidated line item improvement process (CLIIP). The proposed changes would revise the TSs related to reactor pressure vessel (RPV) water inventory control (WIC) based on Technical Specifications Task Force (TSTF) Traveler TSTF-582, Revision 0, RPV WIC Enhancements (ADAMS Accession No. ML19240A260), and the associated NRC staff safety evaluation (SE) of TSTF-582 (ADAMS Accession No. ML20219A333).

The boiling-water reactor (BWR) RPV design includes multiple penetrations located below the top of active fuel. These penetrations provide entry for control rods, recirculation flow, reactor water cleanup, and shutdown cooling. Since these penetrations are below the top of active fuel, this creates a potential to drain the reactor vessel water inventory and lose effective core cooling. The loss of water inventory and effective core cooling can potentially lead to fuel cladding failure and radioactive release. Drain Time is the time it would take for the water inventory in and above the RPV to drain to the top of active fuel.

1.1 Proposed TS Changes to Adopt TSTF-582 In accordance with NRC-approved TSTF-582, the licensee proposed changes that would revise the TSs related to RPV WIC to incorporate operating experience and correct errors and omissions that the licensee incorporated into the River Bend TSs when adopting TSTF-542, Revision 2, Reactor Pressure Vessel Water Inventory Control (ADAMS Accession No. ML16074A448). Specifically, the licensee proposed the following changes to adopt TSTF-582:

Enclosure 2

The Drain Time definition in River Bend TS 1.1 would be revised to move the examples of common mode failure mechanisms to the Bases and delete seismic events.

In River Bend TS 1.1, Drain Time definition, the exception from considering the Drain Time for penetration flow paths isolated with manual or automatic valves that are locked, sealed, or otherwise secured would be revised to apply the exception for manual or automatic valves that are closed and administratively controlled.

The Actions of River Bend TS 3.3.5.2, Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation, would be revised to permit placing an inoperable isolation channel in trip as an alternative to declaring the associated penetration flow path incapable of automatic isolation.

River Bend TS 3.3.5.2, Required Action B.2, requires calculating Drain Time with a Completion Time of immediately. The Required Action would be renumbered as A.2.2 and revised to state, Initiate action to calculate Drain Time.

River Bend TS 3.3.6.1, Primary Containment and Drywell Isolation Instrumentation, Required Action J.2 would be deleted. This action is no longer applicable after adoption of TSTF-542, Revision 2.

In River Bend TS 3.5.1, ECCS-Operating, Actions Note, the first use of the acronym HPCS [high pressure core spray] would be defined and the definition would be removed from Condition B.

River Bend TS 3.5.2, Reactor Pressure Vessel (RPV) Water Inventory Control, and TS 3.3.5.2 would be revised to eliminate the requirement for a manual emergency core cooling system (ECCS) initiation signal to start the required ECCS injection/spray subsystem, and instead rely on manual valve alignment and pump start. TS 3.5.2 Surveillance Requirements (SRs) related to manual initiation using the ECCS signal (such as verifying automatic alignment of valves on an initiation signal) would be eliminated. Related to this change, the TS 3.3.5.2 functions, SRs, and Actions that only support manual initiation using an ECCS signal (including interlocks and minimum flow instruments) would be eliminated.

River Bend SR 3.5.2.6, which requires operating the required ECCS injection/spray subsystem for at least 10 minutes through the recirculation line, would be modified by the addition of two notes. The first Note would replace the existing SR that the ECCS subsystem be run through the recirculation line with a Note that states that operation may be through the test return line. The second Note would permit crediting normal operation of the low-pressure ECCS subsystem for performance of the SR.

River Bend TS 3.8.2, AC [Alternating Current] Sources - Shutdown, SR 3.8.2.1, would be revised to not require SRs that test the ability of the automatic diesel generator (DG) to start in Modes 4 and 5. TSTF-542, Revision 2, eliminated the automatic ECCS initiation in Modes 4 and 5.

1.2 Additional Proposed TS Changes 1.2.1 Proposed TS Changes to Adopt TSTF-583-T The licensee proposed to make the following changes to the River Bend TSs in accordance with TSTF-583-T, TSTF-582 Diesel Generator Variation (ADAMS Accession No. ML20248H330):

The Applicability of Limiting Condition for Operation (LCO) 3.3.8.1 would be revised to remove the specified condition, which states, When the associated diesel generator (DG) is required to be OPERABLE by LCO 3.8.2, AC Sources - Shutdown.

SR 3.8.2.1 would be revised to add SR 3.8.1.7, SR 3.8.1.11, SR 3.8.1.12, SR 3.8.1.13, SR 3.8.1.15, SR 3.8.1.18 and SR 3.8.2.19 to the list of TS 3.8.1 SRs that are not applicable under SR 3.8.2.1.

1.2.2 Editorial Variations The licensee proposed to delete River Bend LCO 3.3.6.1, Required Actions J.3.1 and J.3.2.

The licensee proposed to change River Bend SR 3.5.2.8 to state: Verify the required ECCS injection/spray subsystem can be manually operated.

2.0 REGULATORY EVALUATION

The regulation at 10 CFR 50.36(c)(2) requires that TSs include LCOs. The regulation at 10 CFR 50.36(c)(2)(i) states, in part, that LCOs are the lowest functional capability or performance levels of equipment required for safe operation of the facility. The regulation also requires, in part, that when an LCO of a nuclear reactor is not met, the licensee shall shut down the reactor or follow any remedial action permitted by the technical specifications until the condition can be met.

The regulation at 10 CFR 50.36(c)(3) requires that TSs include items in the category of SRs, which are requirements relating to test, calibration, or inspection to assure that the necessary quality of systems and components is maintained, that facility operation will be within safety limits, and that the limiting conditions for operation will be met.

The NRC staffs guidance for the review of TSs is in Chapter 16.0, Technical Specifications, of NUREG-0800, Revision 3, Standard Review Plan for the Review of Safety Analysis Reports for Nuclear Power Plants: LWR [Light Water Reactor] Edition (SRP), dated March 2010 (ADAMS Accession No. ML100351425). As described therein, as part of the regulatory standardization effort, the NRC staff has prepared Standard Technical Specifications (STSs) for each of the LWR nuclear designs. Accordingly, the NRC staffs review includes consideration of whether the proposed changes are consistent with the Standard Technical Specifications, General Electric, BWR/6 Plants, NUREG-1434, Volume 1, Specifications, and Volume 2, Bases, Revision 4.0, dated April 2012 (ADAMS Accession Nos. ML12104A195 and ML12104A196, respectively), as modified by NRC-approved travelers.

Traveler TSTF-582 revised the STSs related to RPV WIC to incorporate operating experience and to correct editorial errors in TSTF-542, Revision 2. The NRC approved TSTF-542, Revision 2, on December 20, 2016 (ADAMS Package Accession No. ML16343B066). The NRC

staff approved TSTF-582 under the CLIIP in a letter dated August 13, 2020 (ADAMS Accession No. ML20219A333). The TSTF-582 SE states that a licensee may adopt the STS changes approved in TSTF-582, if the licensee has already adopted the STS changes approved in TSTF-542, Revision 2.

3.0 TECHNICAL EVALUATION

3.1 Proposed TS Changes to Adopt TSTF-582 The NRC staff compared the licensees proposed TS changes in Section 1.1 of this SE against the changes approved in TSTF-582. In accordance with the SRP Chapter 16.0, the NRC staff determined that the STS changes approved in TSTF-582 are applicable to the River Bend TSs because River Bend is a BWR/6 design and the NRC staff approved the TSTF-582 changes for BWR/6 designs. The licensee meets the TSTF-582 SE provision for adoption of TSTF-582 since it adopted traveler TSTF-542, Revision 2, dated November 7, 2018 (ADAMS Accession No. ML18267A341). Therefore, the NRC staff concludes that the licensees proposed changes to the River Bend TSs in Section 1.1 of this SE are acceptable in that they are consistent with TSTF-582 and the terms for use stated in the NRC staff SE of TSTF-582.

The NRC staff finds that the proposed changes to the TS 1.1 definition and LCOs 3.3.5.2, 3.3.6.1, and 3.5.1 for River Bend correctly specify the lowest functional capability or performance levels of equipment required for safe operation of the facility in accordance with 10 CFR 50.36(c)(2)(i). Also, the NRC staff finds that the proposed changes to the Actions of LCOs 3.3.5.2 and 3.5.1 for River Bend are adequate remedial actions to be taken until each LCO can be met to provide protection to the health and safety of the public, thereby satisfying 10 CFR 50.36(c)(2)(i).

The NRC staff finds that the proposed revisions to the SRs in River Bend TSs 3.3.5.2, 3.5.2, and 3.8.2 continue to provide requirements relating to test, calibration, or inspection to assure that the necessary quality of systems and components is maintained, that facility operation will be within safety limits, and that the LCOs will be met in accordance with 10 CFR 50.36(c)(3).

Thus, the proposed changes continue to meet the requirements of 10 CFR 50.36(c)(2)(i) and 50.36(c)(3) as discussed in Section 3.0 of the NRC staffs SE of TSTF-582.

3.2 Additional Proposed TS Changes 3.2.1 Proposed TS Changes to Adopt TSTF-583-T Refer to Section 1.2.1 of this SE for a description of the proposed changes.

3.2.1.1 TS 3.3.8.1, Applicability The licensee stated that TS 3.8.2 does not require automatic start and loading of a DG within 10 seconds for DG 1A and 13 seconds for DG 1B on an ECCS initiation signal or a loss of offsite power signal. Currently, River Bend TS 3.3.8.1, Loss of Power (LOP) Instrumentation, is applicable in Modes 1, 2, and 3, and when the associated DG is required to be operable by TS 3.8.2. The NRC staff confirmed that TS 3.8.2 no longer requires automatic start and loading of a DG on a LOP signal. The NRC staff finds it acceptable to revise the Applicability of LCO 3.3.8.1 by deleting When the associated diesel generator is required to be OPERABLE by LCO 3.8.2, AC Sources - Shutdown, because the LOP instrumentation that generates the

LOP signal does not need to be operable when the DG is required to be operable by TS 3.8.2.

Therefore, the NRC staff concludes that the LCO applicability changes will continue to provide for the lowest functional capability or performance levels of equipment required for safe operation of the facility and, therefore, meet the LCO requirements of 10 CFR 50.36(c)(2).

3.2.1.2 SR 3.8.2.1 LCO 3.8.2, AC Sources - Shutdown, requires one offsite circuit and one DG capable of supplying one division of the onsite Class 1E AC electrical power distribution subsystem(s) required by LCO 3.8.8, Distribution Systems-Shutdown, to be operable in shutdown conditions. The existing SR 3.8.2.1 lists the TS 3.8.1 SRs that are applicable in shutdown conditions with some exceptions.

River Bend SRs 3.8.1.7 and 3.8.1.15 require that the DG 1A and DG 1B start from standby or hot conditions, and achieve required voltage and frequency within 10 and 13 seconds, within required steady-state voltage and frequency ranges. The 10 and 13 second start requirement associated with the DG automatic start supports assumptions in the design basis loss-of-coolant accident analysis. The NRC staff confirmed that the 10 and 13 second timing is not required during a manual DG start to respond to a draining event, which has a minimum Drain Time of 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months . In addition, River Bend SR 3.8.1.2, which requires the DG to start from standby conditions and achieve the required steady-state voltage and frequency ranges, is applicable under SR 3.8.2. The NRC staff finds that the SRs 3.8.1.7 and 3.8.1.15 testing for the DGs capability to achieve required steady-state voltage and frequency ranges will be performed in SR 3.8.1.2 since SR 3.8.1.2 provides the test for this DG capability. Therefore, the NRC staff finds it acceptable to exclude SR 3.8.1.7 and SR 3.8.1.15 from the list of TS 3.8.1 SRs that are applicable under SR 3.8.2.1.

River Bend SR 3.8.1.18 states, [Verify sequence time is within +/-10% of design for each load sequencer timer. This SR verifies the 10 percent load sequence time interval tolerance between each sequenced load block when loads are sequentially connected to the engineered safety features bus by an automatic sequencer while the DG is tied to the engineered safety features bus. River Bend TS 3.5.2 requires manual starting of the equipment for water injection to respond to a draining event so that the DG will be manually loaded during a draining event.

No other postulated events require automatic loading of the DG during shutdown conditions.

The NRC staff confirmed that with respect to SR 3.8.18, the load sequencers are used for the automatic loading of the DG and are not used during a manual loading of the DG. Therefore, the NRC staff finds it acceptable to exclude SR 3.8.1.18 from the list of TS 3.8.1 SRs that are applicable under SR 3.8.2.1.

The NRC staff finds that the proposed changes to revise SR 3.8.2.1 for River Bend are acceptable because the remaining applicable SRs will continue to demonstrate the operability of the required AC power sources and, as such, ensure the availability of the AC power required to operate the plant in a safe manner and mitigate postulated events during shutdown conditions.

Therefore, the NRC staff finds that the proposed changes to SR 3.8.2.1 are acceptable because the changes continue to assure that the necessary quality of systems and components is maintained, that facility operation will be within safety limits, and that the associated LCO will continue to be met in accordance with 10 CFR 50.36(c)(3).

3.2.2 Editorial The NRC staff reviewed the editorial variations proposed by the licensee, described in Section 1.2.2 of this SE.

The licensee proposed to delete River Bend LCO 3.3.6.1, Required Actions J.3.1 and J.3.2.

The licensee stated that the River Bend TSs include LCO 3.3.6.1, Required Actions J.3.1 and J.3.2 that are not included in TSTF-582. The NRC staff reviewed this change and finds it acceptable because with the TSTF-582 deletion of LCO 3.3.6.1 Required Action J.2, Required Actions J.3.1 and J.3.2 are no longer applicable. Required Actions J.3.1 and J.3.2 are intended to allow the residual heat removal shutdown cooling system penetration flow path to remain unisolated when the shutdown cooling function is needed to provide core cooling. The NRC staff finds this change acceptable because it is editorial and does not substantively change the TS requirements.

The licensee proposed to change River Bend SR 3.5.2.8 to state: Verify the required ECCS injection/spray subsystem can be manually operated. SR 3.5.2.8 from the River Bend TS currently states: Verify the required LPCI [low-pressure coolant injection] or LPCS [low-pressure core spray] subsystem actuates on a manual initiation signal, or the required HPCS subsystem can be manually operated. The NRC staff reviewed the change and finds it acceptable because it is editorial and does not substantively change the TS requirements. This change makes River Bend SR 3.5.2.8 consistent with the wording in TSTF-582 SR 3.5.2.6.

Finally, the NRC staff reviewed the proposed TS changes for technical clarity and consistency with the existing requirements for customary terminology and formatting. The NRC staff finds that the proposed changes are consistent with Chapter 16.0 of the SRP and are therefore acceptable.

4.0 STATE CONSULTATION

In accordance with the Commissions regulations, the Louisiana State official was notified of the proposed issuance of the amendment on December 4, 2020. The State official had no comments.

5.0 ENVIRONMENTAL CONSIDERATION

The amendment changes a requirement with respect to the installation or use of a facility component located within the restricted area as defined in 10 CFR Part 20 and changes SRs.

The NRC staff has determined that the amendment involves no significant increase in the amounts, and no significant change in the types, of any effluents that may be released offsite, and that there is no significant increase in individual or cumulative occupational radiation exposure. The NRC has previously issued a proposed finding that the amendment involves no significant hazards consideration, published in the Federal Register on November 3, 2020 (85 FR 69654), and there has been no public comment on such finding. Accordingly, the amendment meets the eligibility criteria for categorical exclusion set forth in 10 CFR 51.22(c)(9).

Pursuant to 10 CFR 51.22(b), no environmental impact statement or environmental assessment need be prepared in connection with the issuance of the amendment.

6.0 CONCLUSION

The Commission has concluded, based on the considerations discussed above, that: (1) there is reasonable assurance that the health and safety of the public will not be endangered by operation in the proposed manner, (2) there is reasonable assurance that such activities will be conducted in compliance with the Commissions regulations, and (3) the issuance of the amendment will not be inimical to the common defense and security or to the health and safety of the public.

Principal Contributor: T. Sweat Date: January 6, 2021

ML20339A518 OFFICE NRR/DORL/LPL4/PM NRR/DORL/LPL4/LA NRR/DSS/STSB/BC NRR/DSS/SCPB/BC NAME PBuckberg PBlechman VCusumano BWittick DATE 12/11/2020 12/10/2020 11/12/2020 11/24/2020 OFFICE OGC - NLO NRR/DORL/LPL4/BC NRR/DORL/LPL4/PM*

NAME KGamin JDixon-Herrity PBuckberg DATE 12/22/2020 1/4/2021 1/6/2021

v t e Letter Sequence Approval
EPID:L-2020-LLA-0204, TSTF-582 (Approved, Closed)
Initiation Request Acceptance Administration Questions Answers Results Approval Other:
MONTHYEAR2020-09-04 [Table View]

ML20339A518