Text

Issuance of Amendment Adoption of Technical Specification Task Force Traveler TSTF-425, Revision 3
	ML19066A008
Person / Time
Site:	River Bend
Issue date:	04/29/2019
From:	O'Banion M; Plant Licensing Branch IV
To:	; Entergy Operations
	Regner, L M, 301-415-1906
References
	EPID L-2018-LLA-0056
	Download: ML19066A008 (176)
	v • d • e

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 April 29, 2019 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 RE:

ADOPTION OF TECHNICAL SPECIFICATIONS TASK FORCE TRAVELER TSTF-425, REVISION 3 (EPID L-2018-LLA-0056)

Dear Sir or Madam:

The U.S. Nuclear Regulatory Commission (NRC) has issued the enclosed Amendment No. 196 to Renewed Facility Operating License No. NPF-47 for the River Bend Station, Unit 1. The amendment consists of changes to the technical specifications in response to your application dated February 28, 2018, as supplemented by letters dated July 10, July 24, December 17, and December 20, 2018.

The amendment revises the TSs by relocating specific surveillance frequencies to a licensee-controlled program consistent with the NRG-approved Technical Specification Task Force (TSTF) Improved Standard Technical Specifications Change Traveler TSTF-425, Revision 3, "Relocate Surveillance Frequencies to Licensee Control - RITSTF [Risk-Informed TSTF] Initiative 5b."

A copy of the related Safety Evaluation is enclosed. The Notice of Issuance will be included in the Commission's biweekly Federal Register notice.

Docket No. 50-458

Enclosures:

1. Amendment No. 196 to NPF-47

2. Safety Evaluation cc: Listserv

?J,v1'1 ~4wo Margaret W. O'Banion, Project Manager Plant Licensing Branch IV Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 ENTERGY LOUISIANA LLC AND ENTERGY OPERATIONS, INC.

DOCKET NO. 50-458 RIVER BEND STATION, UNIT 1 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 196 Renewed License No. NPF-47

1.

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

A.

The application for amendment by Entergy Operations, Inc. (EOI, the licensee),

dated February 28, 2018, as supplemented by letters dated July 10, July 24, December 17, and December 20, 2018, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's rules and regulations set forth in 10 CFR Chapter I;

8.

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 Commission's regulations; D.

The issuance of this license 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 Commission's regulations and all applicable requirements have been satisfied.

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. 196 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.

The license amendment is effective as of its date of issuance and shall be implemented within 90 days from the date of issuance.

Attachment:

FOR THE NUCLEAR REGULATORY COMMISSION Robert J. Pascarelli, Chief Plant Licensing Branch IV Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Changes to the Renewed Facility Operating License No. NPF-47 and Technical Specifications Dateoflssuance: April 29, 2019

ATTACHMENT TO LICENSE AMENDMENT NO. 196 RIVER BEND STATION, UNIT 1 RENEWED FACILITY OPERATING LICENSE NO. NPF-47 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 Am_endment number and contain marginal lines indicating the areas of change.

Renewed Facility Operating License Remove Insert Technical Specifications REMOVE INSERT REMOVE INSERT 3.1-9 3.1-9 3.3-38 3.3-38 3.1-12 3.1-12 3.3-46 3.3-46 3.1-17 3.1-17 3.3-52 3.3-52 3.1-19 3.1-19 3.3-52a 3.1-21 3.1-21 3.3-59 3.3-59 3.1-22 3.1-22 3.3-60 3.3-60 3.1-25 3.1-25 3.3-64 3.3-64 3.2-1 3.2-1 3.3-67 3.3-67 3.2-2 3.2-2 3.3-70 3.3-70 3.2-3 3.2-3 3.3-73 3.3-73 3.2-6 3.2-6 3.3-76 3.3-76 3.3-3 3.3-3 3.3-77 3.3-77 3.3-4 3.3-4 3.4-2 3.4-2 3.3-5 3.3-5 3.4-6 3.4-6 3.3-6 3.3-6 3.4-7 3.4-7 3.3-6a 3.4-9 3.4-9 3.3-12 3.3-12 3.4-11 3.4-11 3.3-13 3.3-13 3.4-13 3.4-13 3.3-14c 3.3-14c 3.4-19 3.4-19 3.3-16 3.3-16 3.4-21 3.4-21 3.3-17 3.3-17 3.4-24 3.4-24 3.3-21 3.3-21 3.4-26 3.4-26 3.3-23 3.3-23 3.4-28 3.4-28 3.3-24 3.3-24 3.4-30 3.4-30 3.3-27 3.3-27 3.4-33 3.4-33 3.3-28 3.3-28 3.5-4 3.5-4 3.3-30 3.3-30 3.5-5 3.5-5 3.3-31 3.3-31 3.5-5a

REMOVE 3.5-8 3.5-9 3.5-11 3.5-12 3.6-7 3.6-8 3.6-15 3.6-16 3.6-17 3.6-18 3.6-21 3.6-22 3.6-24 3.6-26 3.6-29 3.6-30 3.6-32 3.6-35 3.6-36 3.6-38 3.6-42 3.6-43 3.6-45 3.6-46 3.6-47 3.6-50 3.6-52 3.6-55 3.6-59 3.6-60 3.6-61 3.6-62 3.6-66 3.6-69 3.6-70 3.6-71 3.6-72 3.7-3 3.7-4 3.7-7 3.7-11 3.7-13 3.7-14a 3.7-15 3.8-5 Technical Specifications (continued)

INSERT 3.5-8 3.5-9 3.5-11 3.5-12 3.6-7 3.6-8 3.6-15 3.6-16 3.6-17 3.6-18 3.6-21 3.6-22 3.6-24 3.6-26 3.6-29 3.6-30 3.6-32 3.6-35 3.6-36 3.6-38 3.6-42 3.6-43 3.6-45 3.6-46 3.6-47 3.6-50 3.6-52 3.6-55 3.6-59 3.6-60 3.6-61 3.6-62 3.6-66 3.6-69 3.6-70 3.6-71 3.6-72 3.7-3 3.7-4 3.7-7 3.7-11 3.7-13 3.7-14a 3.7-15 3.8-5 REMOVE 3.8-6 3.8-7 3.8-8 3.8-9 3.8-10 3.8-11 3.8-12 3.8-13 3.8-14 3.8-15 3.8-16 3.8-23 3.8-25 3.8-26 3.8-27 3.8-32 3.8-33 3.8-35 3.8-37 3.8-40 3.8-42 3.9-1a 3.9-2 3.9-3 3.9-4 3.9-7 3.9-8 3.9-9 3.9-11 3.9-13 3.10-5 3.10-8 3.10-11 3.10-12 3.10-14 3.10-15 3.10-17 3.10-21 3.10-22 5.0-11 5.0-12 5.0-13 5.0-14 5.0-16 5.0-16a INSERT 3.8-6 3.8-7 3.8-8 3.8-9 3.8-10 3.8-11 3.8-12 3.8-13 3.8-14 3.8-15 3.8-16 3.8-23 3.8-25 3.8-26 3.8-27 3.8-32 3.8-33 3.8-35 3.8-37 3.8-40 3.8-42 3.9-1a 3.9-2 3.9-3 3.9-4 3.9-7 3.9-8 3.9-9 3.9-11 3.9-13 3.10-5 3.10-8 3.10-11 3.10-12 3.10-14 3.10-15 3.10-17 3.10-21 3.10-22 5.0-11 5.0-12 5.0-13 5.0-14 5.0-16 5.0-16a 5.0-16b (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 Commission's 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)

(2)

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.

Technical Specifications and Environmental Protection Plan The Technical Specifications contained in Appendix A, as revised through Amendment No. 196 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. 196

Control Rod OPERABILITY 3.1.3 SURVEILLANCE REQUIREMENTS SR 3.1.3.1 SR 3.1.3.2 SR 3.1.3.3 SR 3.1.3.4 RIVER BEND SURVEILLANCE Determine the position of each control rod.

DELETED

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

Not required to be performed until 31 days after the control rod is withdrawn and THERMAL POWER is greater than the LPSP of the RPCS.

FREQUENCY In accordance with the Surveillance Frequency Control Program Insert each withdrawn control rod at least one notch.

In accordance with the Surveillance Frequency Control Program Verify each control rod scram time from fully withdrawn to notch position 13 is ::; 7 seconds.

3.1-9 In accordance with SR 3.1.4.1, SR 3.1.4.2, SR 3.1.4.3, and SR 3.1.4.4 (continued)

Amendment No. 84, 484, 196

Control Rod Scram Times 3.1.4 SURVEILLANCE REQUIREMENTS

N()TE------------------------------------------------------------

During single control rod scram time Surveillances, the control rod drive (CRD) pumps shall be isolated from the associated scram accumulator.

SR 3.1.4.1 SR 3.1.4.2 SR 3.1.4.3 RIVER BEND SURVEILLANCE Verify each control rod scram time is within the limits of Table 3.1.4-1 with reactor steam dome pressure 2:: 950 psig.

Verify, for a representative sample, each tested control rod scram time is within the limits of Table 3.1.4-1 with reactor steam dome pressure 2:: 950 psig.

Verify each affected control rod scram time is within the limits of Table 3.1.4-1 with any reactor steam dome pressure.

FREQUENCY Prior to exceeding 40% RTP after each reactor shutdown 2:: 120 days In accordance with the Surveillance Frequency Control Program Prior to declaring control rod OPERABLE after work on control rod or CRD System that could affect scram time (continued) 3.1-12 Amendment No. 81 126, 4-ee, 196

ACTIONS (continued)

CONDITION C.

(continued)

C.2 D.

Required Action and D. 1 associated Completion Time of Required Action B.1 or C.1 not met.

SURVEILLANCE REQUIREMENTS Control Rod Scram Accumulators 3.1.5 REQUIRED ACTION COMPLETION TIME Declare the associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months control rod inoperable.

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

Not applicable if all inoperable control rod scram accumulators are associated with fully inserted control rods.

Place the reactor mode Immediately switch in the shutdown position.

SURVEILLANCE FREQUENCY SR 3.1.5.1 RIVER BEND Verify each control rod scram accumulator pressure is ;:: 1540 psig.

In accordance with the Surveillance Frequency Control Program 3.1-17 Amendment No. 3-i, 444, 196

ACTIONS (continued)

CONDITION B.

Nine or more OPERABLE control rods not in compliance with BPWS.

REQUIRED ACTION B.1 ----------NOTE---------

Affected control rods may be bypassed in RACS in accordance with SR 3.3.2.1.9 for insertion only.

Suspend withdrawal of control rods.

Control Rod Pattern 3.1.6 COMPLETION TIME Immediately B.2 Place the reactor mode 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months switch in the shutdown position.

SURVEILLANCE REQUIREMENTS SR 3.1.6.1 RIVER BEND SURVEILLANCE Verify all OPERABLE control rods comply with BPWS.

3.1-19 FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment No. 84, 196

SURVEILLANCE REQUIREMENTS SR 3.1.7.1 SR 3.1.7.2 SR 3.1.7.3 SR 3.1.7.4 SURVEILLANCE

N()TE-----------------------------

The minimum required available solution volume is determined by the performance of SR 3.1. 7.5.

Verify available volume of sodium pentaborate solution is greater than or equal to the minimum required available solution volume.

Verify temperature of sodium pentaborate solution is 2 45°F.

NC>TE---------------------------------

Sodium Pentaborate Concentration (C), in weight percent, is determined by the performance of SR 3.1.7.5. Boron-10 enrichment (E), in atom percent, is determined by the performance of SR 3.1.7.9.

Verify that the SLC System satisfies the following equation:

(C)(E) 2 570 Verify continuity of explosive charge.

SLC System 3.1.7 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued)

RIVER BEND 3.1-21 Amendment No. 34-, 444, 196

SURVEILLANCE REQUIREMENTS (continued)

SR 3.1.7.5 SR 3.1.7.6 SR 3.1.7.7 SR 3.1.7.8 SURVEILLANCE Verify the available weight of Boron-10 is~ 170 lbs, and the percent weight concentration of sodium pentaborate in solution is ~ 9.5% by weight, and determine the minimum required available solution volume.

Verify each SLC subsystem manual, power operated, and automatic valve in the flow path that is not locked, sealed, or otherwise secured in position, is in the correct position, or can be aligned to the correct position.

Verify each pump develops a flow rate ~ 41.2 gpm at a discharge pressure~ 1250 psig.

Verify flow through one SLC subsystem from pump into reactor pressure vessel.

SLC System 3.1.7 FREQUENCY In accordance with the Surveillance Frequency Control Program Once within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after water or boron is added to solution Once within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after solution temperature is restored to ~ 45°F In accordance with the Surveillance Frequency Control Program In accordance with the lnservice Testing Program In accordance with the Surveillance Frequency Control Program (continued)

RIVER BEND 3.1-22 Amendment No. 81 114, 4-,eg, 196

SDV Vent and Drain Valves 3.1.8 SURVEILLANCE REQUIREMENTS SR 3.1.8.1 SR 3.1.8.2 SR 3.1.8.3 RIVER BEND SURVEILLANCE

N()TE---------------------------------

Not required to be met on vent and drain valves closed during performance of SR 3.1.8.2.

Verify each SDV vent and drain valve is open.

Cycle each SDV vent and drain valve to the fully closed and fully open position.

Verify each SDV vent and drain valve:

a.

Closes in::; 30 seconds after receipt of an actual or simulated scram signal; and

b.

Opens when the actual or simulated scram signal is reset.

FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program 3.1-25 Amendment No. 84, 498, 196

3.2 POWER DISTRIBUTION LIMITS APLHGR 3.2.1 3.2.1 AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR)

LCO 3.2.1 All APLHGRs shall be less than or equal to the limits specified in the COLR.

APPLICABILITY:

THERMAL POWER 2 23.8% RTP.

ACTIONS CONDITION REQUIRED ACTION A.

Any APLHGR not within A.1 Restore APLHGR(s) to within limits.

limits.

B.

Required Action and B.1 Reduce THERMAL POWER associated Completion to < 23.8% RTP.

Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.2.1.1 Verify all APLHGRs are less than or equal to the limits specified in the COLR.

COMPLETION TIME 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months 4 hours FREQUENCY Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after 2 23.8% RTP In accordance with the Surveillance Frequency Control Program RIVER BEND 3.2-1 Amendment No. 84, 444, 196

3.2 POWER DISTRIBUTION LIMITS 3.2.2 MINIMUM CRITICAL POWER RATIO (MCPR)

MCPR 3.2.2 LCO 3.2.2 All MCPRs shall be greater than or equal to the MCPR operating limits specified in the COLR.

APPLICABILITY:

THERMAL POWER~ 23.8% RTP.

ACTIONS CONDITION REQUIRED ACTION A.

Any MCPR not within A.1 Restore MCPR(s) to within limits.

limits.

B.

Required Action and B.1 Reduce THERMAL POWER associated Completion to < 23.8% RTP.

Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.2.2.1 Verify all MCPRs are greater than or equal to the limits specified in the COLR.

COMPLETION TIME 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months 4 hours FREQUENCY Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after 2 23.8% RTP In accordance with the Surveillance Frequency Control Program RIVER BEND 3.2-2 Amendment No. 84, 444, 196

3.2 POWER DISTRIBUTION LIMITS 3.2.3 LINEAR HEAT GENERATION RATE (LHGR)

LHGR 3.2.3 LCO 3.2.3 All LHGRs shall be less than or equal to the limits specified in the COLR.

APPLICABILITY:

THERMAL POWER~ 23.8% RTP.

ACTIONS CONDITION REQUIRED ACTION A.

Any LHGR not within A.1 Restore LHGR(s) to within limits.

limits.

B.

Required Action and B.1 Reduce THERMAL POWER associated Completion to < 23.8% RTP.

Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.2.3.1 Verify all LHGRs are less than or equal to the limits specified in the COLR.

COMPLETION TIME 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months 4 hours FREQUENCY Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after

~ 23.8% RTP In accordance with the Surveillance Frequency Control Program RIVER BEND 3.2-3 Amendment No. 84, 444, 196

SURVEILLANCE REQUIREMENTS SR 3.2.4.1 SURVEILLANCE

N()TE ----------------------------------

Not required to be performed until 15 minutes after entry into the Restricted Region if entry was the result of an unexpected transient.

Verify FCBB ::;:; 1.0.

FCBB 3.2.4 FREQUENCY In accordance with the Surveillance Frequency Control Program Once within 15 minutes following unexpected transient RIVER BEND 3.2-6 Amendment No. 4-0e, 196

SURVEILLANCE REQUIREMENTS RPS Instrumentation 3.3.1.1

N()TES---------------------------------------------------------

1.

Refer to Table 3.3.1.1-1 to determine which SRs apply for each RPS Function.

2.

When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Function maintains RPS trip capability.

SR 3.3.1.1.1 SR 3.3.1.1.2 SR 3.3.1.1.3 SURVEILLANCE Perform CHANNEL CHECK.

N()TE----------------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after THERMAL P()WER :2'. 23.8% RTP.

Verify the absolute difference between the average power range monitor (APRM) channels and the calculated power~ 2% RTP<al.

Adjust the flow control trip reference card to conform to reactor flow(bl.

FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program

()nee within 7 days after reaching equilibrium conditions following refueling outage.

(a) For a period of 30 days beginning with uprate C()LR implementation and corresponding plant monitoring computer data bank changes the difference between the average power range monitor (APRM) channels and the calculated power must be within -2% RTP to

+7% RTP.

(b) Within 30 days of uprate C()LR implementation and corresponding plant monitoring computer data bank changes the flow control trip reference card will be verified to conform to reactor flow in accordance with the uprated C()LR.

(continued)

RIVER BEND 3.3-3 Amendment No. 81 100 106, -144, 196

RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued)

SR 3.3.1.1.4 SR 3.3.1.1.5 SR 3.3.1.1.6 SR 3.3.1.1.7 SR 3.3.1.1.8 RIVER BEND SURVEILLANCE

NC>TE----------------------------

Not required to be performed when entering M()DE 2 from MODE 1 until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering M()DE 2.

Perform CHANNEL FUNCTIONAL TEST.

Verify the source range monitor (SRM) and intermediate range monitor (IRM) channels overlap.

NC>TE----------------------------

()nly required to be met during entry into MC>DE 2 from MODE 1.

Verify the IRM and APRM channels overlap.

Calibrate the local power range monitors.

FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Prior to withdrawing SRMs from the fully inserted position In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) 3.3-4 Amendment No. 81 100 106 107,444, 196

SURVEILLANCE REQUIREMENTS (continued}

SR 3.3.1.1.9 SR 3.3.1.1.10 SR 3.3.1.1.11 SR 3.3.1.1.12 SURVEILLANCE Perform CHANNEL FUNCTIONAL TEST.

Calibrate the trip units.

NOTES--------------------------

1.

Neutron detectors and flow reference transmitters are excluded.

2.

For Function 2.a, not required to be performed when entering MODE 2 from MODE 1 until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 2.

3.

For Function 2.b. the digital components of the flow control trip reference cards are excluded.

Perform CHANNEL CALIBRATION.

Perform CHANNEL FUNCTIONAL TEST.

RPS Instrumentation 3.3.1.1 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued)

RIVER BEND 3.3-5 Amendment No. 81 106 114, eS, 196

SURVEILLANCE REQUIREMENTS (continued)

SR 3.3.1.1.13 SR 3.3.1.1.14 SR 3.3.1.1.15 SR 3.3.1.1.16 SR 3.3.1.1.17 SURVEILLANCE

NC>TES------------------------

1.

Neutron detectors are excluded.

2.

For IRMs, not required to be performed when entering MODE 2 from MODE 1 until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MC>DE 2.

Perform CHANNEL CALIBRATION.

Verify the APRM Flow Biased Simulated Thermal Power-High time constant is within the limits specified in the COLR.

Perform LC>GIC SYSTEM FUNCTIC>NAL TEST.

Verify Turbine Stop Valve Closure and Turbine Control Valve Fast Closure Trip ()ii Pressure-Low Functions are not bypassed when THERMAL POWER is~ 40% RTP.

Calibrate the flow reference transmitters.

RPS Instrumentation 3.3.1.1 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued)

RIVER BEND 3.3-6 Amendment No. 81 106 114, -1,.eg, 196

SURVEILLANCE REQUIREMENTS continued SR 3.3.1.1.18 RIVER BEND SURVEILLANCE

NC>TES------------------------------

1.

Neutron detectors are excluded.

2.

For Functions 3, 4, and 5 in Table 3.3.1.1-1, the channel sensors are excluded.

Verify the RPS RESPC>NSE TIME is within limits.

3.3-6a RPS Instrumentation 3.3.1.1 FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment No. 196

SURVEILLANCE REQUIREMENTS SRM Instrumentation 3.3.1.2

N()TE---------------------------------------------------------------

Refer to Table 3.3.1.2-1 to determine which SRs apply for each applicable MODE or other specified conditions.

SR 3.3.1.2.1 SR 3.3.1.2.2 SR 3.3.1.2.3 RIVER BEND SURVEILLANCE Perform CHANNEL CHECK.

FREQUENCY In accordance with the Surveillance Frequency Control Program

NOTES-----------------------------

1.

Only required to be met during CORE ALTERATIONS.

2.

()ne SRM may be used to satisfy more than one of the following.

Verify an ()PERABLE SRM detector is located in:

a.

The fueled region;

b.

The core quadrant where CORE AL TERA Tl()NS are being performed when the associated SRM is included in the fueled region; and

c.

A core quadrant adjacent to where CORE ALTERATl()NS are being performed, when the associated SRM is included in the fueled region.

Perform CHANNEL CHECK.

3.3-12 In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program

( continued)

Amendment No. M, 196

SURVEILLANCE REQUIREMENTS (continued}

SR 3.3.1.2.4 SR 3.3.1.2.5 SR 3.3.1.2.6 SURVEILLANCE

N()TE------------------------------

Not required to be met with less than or equal to four fuel assemblies adjacent to the SRM and no other fuel assemblies in the associated core quadrant.

Verify count rate is:

a.

3.0 cps, or

b.

0. 7 cps with a signal to noise ratio ;

:: 2: 1.

N()TE-------------------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after IRMs on Range 2 or below.

Perform CHANNEL FUNCTl()NAL TEST.

N()TES--------------------------------

1.

Neutron detectors are excluded.

2.

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after IRMs on Range 2 or below.

Perform CHANNEL CALIBRATl()N.

SRM Instrumentation 3.3.1.2 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program RIVER BEND 3.3-13 Amendment No. 84, 498, 196

SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.3.1.3.1 Verify each OPERABLE channel of PBDS instrumentation not in Hi-Hi DR Alarm.

SR 3.3.1.3.2 Perform CHANNEL CHECK.

SR 3.3.1.3.3 Perform CHANNEL FUNCTIONAL TEST.

RIVER BEND 3.3-14c PBDS 3.3.1.3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment No. 400, 196

Control Rod Block Instrumentation 3.3.2.1 SURVEILLANCE REQUIREMENTS

N()TES----------------------------------------------------------------

1.

Refer to Table 3.3.2.1-1 to determine which SRs apply for each Control Rod Block Function.

2.

When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Function maintains control rod block capability.

SR 3.3.2.1.1 SR 3.3.2.1.2 SR 3.3.2.1.3 RIVER BEND SURVEILLANCE

N()TE--------------------------------

Not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after THERMAL P()WER is greater than the RWL high power setpoint (HPSP).

Perform CHANNEL FUNCTl()NAL TEST.

N()TE--------------------------------

Not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after THERMAL P()WER is > 35% RTP and less than or equal to the RWL HPSP.

Perform CHANNEL FUNCTl()NAL TEST.

N()TE-----------------------------

Not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after any control rod is withdrawn in M()DE 2.

Perform CHANNEL FUNCTl()NAL TEST.

FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) 3.3-16 Amendment No. 3-t, 196

Control Rod Block Instrumentation 3.3.2.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.2.1.4

NC>TE------------------------------

Not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after THERMAL PC>WER is ~ 10% RTP in MC>DE 1.

Perform CHANNEL FUNCTIC>NAL TEST.

In accordance with the Surveillance Frequency Control Program SR 3.3.2.1.5 Calibrate the low power setpoint trip units. The In accordance with Allowable Value shall be > 10% RTP and the Surveillance

~ 35% RTP.

Frequency Control Program SR 3.3.2.1.6 Verify the RWL high power Function is not In accordance with bypassed when THERMAL POWER is the Surveillance

> 68.2% RTP.

Frequency Control Program SR 3.3.2.1. 7 Perform CHANNEL CALIBRATIC>N.

In accordance with the Surveillance Frequency Control Program SR 3.3.2.1.8

NC>TE----------------------------

Not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after reactor mode switch is in the shutdown position.

Perform CHANNEL FUNCTIC>NAL TEST.

In accordance with the Surveillance Frequency Control Program SR 3.3.2.1.9 Verify the bypassing and movement of control rods Prior to and during required to be bypassed in Rod Action Control the movement of System (RACS) is in conformance with applicable control rods analyses by a second licensed operator or other bypassed in qualified member of the technical staff.

RACS RIVER BEND 3.3-17 Amendment No. 81 118, M, 196

PAM Instrumentation 3.3.3.1 SURVEILLANCE REQUIREMENTS

N()TE-----------------------------------------------------------

These SRs apply to each Function in Table 3.3.3.1-1.

SR 3.3.3.1.1 SR 3.3.3.1.2 SR 3.3.3.1.3 RIVER BEND SURVEILLANCE Perform CHANNEL CHECK.

Deleted FREQUENCY In accordance with the Surveillance Frequency Control Program Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Program 3.3-21 Amendment No. 81 142, 498, 196

3.3 INSTRUMENTATION 3.3.3.2 Remote Shutdown System Remote Shutdown System 3.3.3.2 LCO 3.3.3.2 The Remote Shutdown System Functions shall be OPERABLE.

APPLICABILITY:

MODES 1 and 2.

ACTIONS

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

Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION A.

One or more required A.1 Restore required Function Functions inoperable.

to OPERABLE status.

8.

Required Action and 8.1 Be in MODE 3.

associated Completion Time not met.

SURVEILLANCE REQUIREMENTS SR 3.3.3.2.1 SURVEILLANCE Perform CHANNEL CHECK for each required instrumentation channel that is normally energized.

COMPLETION TIME 30 days 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months FREQUENCY In accordance with the Surveillance Frequency Control Program (continued)

RIVER BEND 3.3-23 Amendment No. 84, 4-ae, 196

SURVEILLANCE REQUIREMENTS (continued)

SR 3.3.3.2.2 SR 3.3.3.2.3 SURVEILLANCE Verify each required control circuit and transfer switch is capable of performing the intended functions.

Perform CHANNEL CALIBRATION for each required instrumentation channel, except valve position instrumentation.

Remote Shutdown System 3.3.3.2 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program RIVER BEND 3.3-24 Amendment No. 84, 498, 196

EOC-RPT Instrumentation 3.3.4.1 SURVEILLANCE REQUIREMENTS

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

When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , provided the associated Function maintains EOC-RPT trip capability.

SR 3.3.4.1.1 SR 3.3.4.1.2 SR 3.3.4.1.3 SR 3.3.4.1.4 SR 3.3.4.1.5 RIVER BEND SURVEILLANCE Perform CHANNEL FUNCTIONAL TEST.

Calibrate the trip units.

Perform CHANNEL CALIBRATION. The Allowable Values shall be:

a.

TSV Closure:::; 7% closed.

b.

TCV Fast Closure, Trip Oil Pressure -

Low: ~ 465 psig.

Perform LOGIC SYSTEM FUNCTIONAL TEST, including breaker actuation.

Verify TSV Closure and TCV Fast Closure, Trip Oil Pressure -

Low Functions are not bypassed when THERMAL POWER is~ 40% RTP.

FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) 3.3-27 Amendment No. 84, 468, 196

EOC-RPT Instrumentation 3.3.4.1 SURVEILLANCE REQUIREMENTS (continued)

SR 3.3.4.1.6 SR 3.3.4.1. 7 RIVER BEND SURVEILLANCE

N()TE-------------------------------

Breaker interruption time may be assumed from the most recent performance of SR 3.3.4.1. 7.

Verify the E()C-RPT SYSTEM RESP()NSE TIME is within limits.

FREQUENCY In accordance with the Surveillance Frequency Control Program Determine RPT breaker interruption time.

In accordance with the Surveillance Frequency Control Program 3.3-28 Amendment No. 34-, 488, 196

ACTIONS (continued)

CONDITION B.

One Function with A lWS-RPT trip capability not maintained.

C.

Both Functions with REQUIRED ACTION B.1 Restore A lWS-RPT trip capability.

C. 1 Restore A lWS-RPT trip AlWS-RPT Instrumentation 3.3.4.2 COMPLETION TIME 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months 1 hour A lWS-RPT trip capability capability for one Function.

not maintained.

D.

Required Action and D. 1 Remove the associated 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion recirculation pump from Time not met.

service.

OR 0.2 Be in MODE 2.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months SURVEILLANCE REQUIREMENTS

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

When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Function maintains AlWS-RPT trip capability.

SURVEILLANCE SR 3.3.4.2.1 Perform CHANNEL CHECK.

RIVER BEND 3.3-30 FREQUENCY In accordance with the Surveillance Frequency Control Program (continued)

Amendment No. 3-i, 196

AlWS-RPT Instrumentation 3.3.4.2 SURVEILLANCE REQUIREMENTS (continued)

SR 3.3.4.2.2 SR 3.3.4.2.3 SR 3.3.4.2.4 SR 3.3.4.2.5 RIVER BEND SURVEILLANCE Perform CHANNEL FUNCTIONAL TEST.

Calibrate the trip units.

Perform CHANNEL CALIBRATION. The Allowable Values shall be:

a.

Reactor Vessel Water Level-Low Low, Level 2: ~-47inches;and

b.

Reactor Steam Dome Pressure-High:

~ 1165 psig.

Perform LOGIC SYSTEM FUNCTIONAL TEST, including breaker actuation.

FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program 3.3-31 Amendment No. 81 114, 498, 196

SURVEILLANCE REQUIREMENTS ECCS Instrumentation 3.3.5.1

N()TES-------------------------------------------------------

1.

Refer to Table 3.3.5.1-1 to determine which SRs apply for each ECCS Function.

2.

When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed as follows: (a) for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Functions 3.c, 3.f, 3.g, and 3.h; and (b) for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Functions other than 3.c, 3.f, 3.g, and 3.h, provided the associated Function or the redundant Function maintains ECCS initiation capability.

SURVEILLANCE FREQUENCY SR 3.3.5.1.1 Perform CHANNEL CHECK.

In accordance with the Surveillance Frequency Control Program SR 3.3.5.1.2 Perform CHANNEL FUNCTIONAL TEST.

In accordance with the Surveillance Frequency Control Program SR 3.3.5.1.3 Calibrate the trip unit.

In accordance with the Surveillance Frequency Control Program SR 3.3.5.1.4 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Program SR 3.3.5.1.5 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Program SR 3.3.5.1.6 Perform LOGIC SYSTEM FUNCTIONAL TEST.

In accordance with the Surveillance Frequency Control Program RIVER BEND 3.3-38 Amendment No. 84, 498, 196

RCIC System Instrumentation 3.3.5.3 SURVEILLANCE REQUIREMENTS

N()TES---------------------------------------------------------------

1.

Refer to Table 3.3.5.3-1 to determine which SRs apply for each RCIC Function.

2.

When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed as follows: (a) for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Functions 2 and 5; and (b) for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Functions 1, 3, and 4 provided the associated Function maintains RCIC initiation capability.

SR 3.3.5.3.1 SR 3.3.5.3.2 SR 3.3.5.3.3 SR 3.3.5.3.4 SR 3.3.5.3.5 RIVER BEND SURVEILLANCE Perform CHANNEL CHECK.

Perform CHANNEL FUNCTIONAL TEST.

Calibrate the trip units.

Perform CHANNEL CALIBRATION.

Perform LOGIC SYSTEM FUNCTIONAL TEST.

FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program 3.3-46 Amendment No. 84, 498, 4-W, 196

Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 SURVEILLANCE REQUIREMENTS

N()TES------------------------------------------------------------

1.

Refer to Table 3.3.6.1-1 to determine which SRs apply for each Function.

2.

When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , provided the associated Function maintains isolation capability.

SURVEILLANCE FREQUENCY SR 3.3.6.1.1 Perform CHANNEL CHECK.

In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.2 Perform CHANNEL FUNCTl()NAL TEST.

In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.3 Calibrate the trip unit.

In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.4 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.5 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Program SR 3.3.6.1.6 Perform L()GIC SYSTEM FUNCTl()NAL TEST.

In accordance with the Surveillance Frequency Control Program (continued)

RIVER BEND 3.3-52 Amendment No. 84, 4-&8, 196

Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 SURVEILLANCE REQUIREMENTS (continued)

SR 3.3.6.1. 7 RIVER BEND SURVEILLANCE

N()TE-----------------------------

Channel sensors are excluded.

Verify the IS()LATl()N SYSTEM RESPONSE TIME for the Main Steam Isolation Valves is within limits.

3.3-52a FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment No. 196

Secondary Containment and Fuel Building Isolation Instrumentation 3.3.6.2 ACTIONS ( continued)

CONDITION REQUIRED ACTION COMPLETION TIME C.

(continued)

C.1.2 Declare associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months isolation dampers inoperable.

AND C.2.1 Place the associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ventilation subsystem in operation.

OR C.2.2 Declare associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ventilation subsystem inoperable.

SURVEILLANCE REQUIREMENTS

NOTES------------------------------------------------------------

1.

Refer to Table 3.3.6.2-1 to determine which SRs apply for each Isolation Function.

2.

When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , provided the associated Function maintains secondary containment isolation capability.

SURVEILLANCE SR 3.3.6.2.1 Perform CHANNEL CHECK.

SR 3.3.6.2.2 Perform CHANNEL FUNCTIONAL TEST.

RIVER BEND 3.3-59 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued)

Amendment No. 84-, 44-J, 196

Secondary Containment and Fuel Building Isolation Instrumentation 3.3.6.2 SURVEILLANCE REQUIREMENTS (continued)

SR 3.3.6.2.3 SR 3.3.6.2.4 SR 3.3.6.2.5 RIVER BEND SURVEILLANCE Calibrate the trip unit.

Perform CHANNEL CALIBRATION.

FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Perform LOGIC SYSTEM FUNCTIONAL TEST.

In accordance with the Surveillance Frequency Control Program 3.3-60 Amendment No. 81 11 a,.ieg, 196

Containment Unit Cooler System Instrumentation 3.3.6.3 SURVEILLANCE REQUIREMENTS

NC>TES-----------------------------------------------------------

1.

Refer to Table 3.3.6.3-1 to determine which SRs apply for each Containment Unit Cooler System Function.

2.

When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , provided the associated Function maintains containment unit cooler initiation capability.

SURVEILLANCE FREQUENCY SR 3.3.6.3.1 Perform CHANNEL CHECK.

In accordance with the Surveillance Frequency Control Program SR 3.3.6.3.2 Perform CHANNEL FUNCTIC>NAL TEST.

In accordance with the Surveillance Frequency Control Program SR 3.3.6.3.3 Calibrate the trip unit.

In accordance with the Surveillance Frequency Control Program SR 3.3.6.3.4 Perform CHANNEL CALIBRATIC>N.

In accordance with the Surveillance Frequency Control Program SR 3.3.6.3.5 Perform LC>GIC SYSTEM FUNCTIC>NAL TEST.

In accordance with the Surveillance Frequency Control Program RIVER BEND 3.3-64 Amendment No. 84, 4-eS, 196

Relief and LLS Instrumentation 3.3.6.4 SURVEILLANCE REQUIREMENTS

N()TE---------------------------------------------------------------

When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , provided the associated Function maintains LLS or relief initiation capability, as applicable.

SR 3.3.6.4.1 SR 3.3.6.4.2 SR 3.3.6.4.3 SR 3.3.6.4.4 RIVER BEND SURVEILLANCE Perform CHANNEL FUNCTl()NAL TEST.

Calibrate the trip unit.

Perform CHANNEL CALIBRATl()N. The Allowable Values shall be:

a.

Relief Function Low:

Medium:

High:

1133 +/- 15 psig 1143 +/- 15 psig 1153 +/- 15 psig

b.

LLS Function Low open:

1063 +/- 15 psig close:

956 +/- 15 psig Medium open:

11 03 +/- 15 psig close:

966 +/- 15 psig High open:

1143 +/- 15 psig close:

976 +/- 15 psig Perform LOGIC SYSTEM FUNCTIONAL TEST.

FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program 3.3-67 Amendment No. 81 114, ~. 196

SURVEILLANCE REQUIREMENTS CRFA System Instrumentation 3.3.7.1

N()TES--------------------------------------------------------. ---

1.

Refer to Table 3.3.7.1-1 to determine which SRs apply for each Function.

2.

When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Function maintains CRFA initiation capability.

SURVEILLANCE FREQUENCY SR 3.3.7.1.1 Perform CHANNEL CHECK.

In accordance with the Surveillance Frequency Control Progr'.3m SR 3.3.7.1.2 Perform CHANNEL FUNCTl()NAL TEST.

In accordance with the Surveillance Frequency Control Program SR 3.3.7.1.3

Calibrate the trip units.

In accordance with the Surveillance Frequency Control Program SR 3.3.7.1.4 Perform CHANNEL CALIBRATl()N.

In accordance with the Surveillance Frequency Control Program SR 3.3.7.1.5 Perform L()GIC SYSTEM FUNCTl()NAL TEST.

In accordance with the Surveillance Frequency Control Program RIVER BEND 3.3-70 Amendment No. 84, 4,eg, 196

SURVEILLANCE REQUIREMENTS LOP Instrumentation 3.3.8.1

NOTES----------------------------------------------------------

1.

Refer to Table 3.3.8.1-1 to determine which SRs apply for each LOP Function.

2.

When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months provided the associated Function maintains DG initiation capability.

SR 3.3.8.1.1 SR 3.3.8.1.2 SR 3.3.8.1.3 SR 3.3.8.1.4 RIVER BEND SURVEILLANCE Perform CHANNEL CHECK.

Perform CHANNEL FUNCTIONAL TEST.

Perform CHANNEL CALIBRATION.

Perform LOGIC SYSTEM FUNCTIONAL TEST.

FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program 3.3-73 Amendment No. 81 168, 4+9, 196

RPS Electric Power Monitoring 3.3.8.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D.

Required Action and D.1 Initiate action to fully insert all Immediately associated Completion insertable control rods in core Time of Condition A or B cells containing one or more not met in MODE 4 or 5 fuel assemblies.

with any control rod withdrawn from a core cell containing one or more fuel assemblies.

SURVEILLANCE REQUIREMENTS SR 3.3.8.2.1 RIVER BEND SURVEILLANCE

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

Only required to be performed prior to entering MODE 2 or 3 from MODE 4, when in MODE 4 for

~ 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

Perform CHANNEL FUNCTIONAL TEST.

3.3-76 FREQUENCY In accordance with the Surveillance Frequency Control Program (continued)

Amendment No. 84, 196

RPS Electric Power Monitoring 3.3.8.2 SURVEILLANCE REQUIREMENTS (continued)

SR 3.3.8.2.2 SR 3.3.8.2.3 RIVER BEND SURVEILLANCE FREQUENCY Perform CHANNEL CALIBRATION. The Allowable In accordance with Values shall be:

the Surveillance

a.

Overvoltage Bus A~ 132 V Bus B ~ 132 V

b.

Undervoltage Bus A~ 115 V Bus B ~ 115 V

c.

Underfrequency (with time delay set to ~ 4.0 seconds.)

Bus A~ 57 Hz Bus B ~ 57 Hz Perform a system functional test.

Frequency Control Program In accordance with the Surveillance Frequency Control Program 3.3-77 Amendment No. 84, 498, 196

Recirculation Loops Operating 3.4.1 ACTIONS (continued)

CONDITION REQUIRED ACTION C.

Requirements B.3, B.4, or C.1 Satisfy the requirements of B.5 of the LCO not met.

the LCO.

D.

Required actions and D.1 Be in Mode 3.

associated completion times of conditions A, B, or C not met.

OR No recirculation loops in operation.

SURVEILLANCE REQUIREMENTS SR 3.4.1.1 SURVEILLANCE

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

Not required to be performed until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after both recirculation loops are in operation.

Verify recirculation loop jet pump flow mismatch with both recirculation loops in operation is:

a.

10% of rated core flow when operating at

< 70% of rated core flow; and

b.

5% of rated core flow when operating at

~ 70% of rated core flow.

COMPLETION TIME 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months 12 hours FREQUENCY In accordance with the Surveillance Frequency Control Program RIVER BEND 3.4-2 Amendment No. 84 97 400, 196

3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.2 Flow Control Valves (FCVs)

FCVs 3.4.2 LCO 3.4.2 A recirculation loop FCV shall be OPERABLE in each operating recirculation loop.

APPLICABILITY:

MODES 1 and 2.

ACTIONS

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

Separate Condition entry is allowed for each FCV.

CONDITION REQUIRED ACTION A.

One or two required FCVs A.1 Lock up the FCV.

inoperable.

B.

Required Action and 8.1 Be in MODE 3.

associated Completion Time not met.

SURVEILLANCE REQUIREMENTS SR 3.4.2.1 SURVEILLANCE Verify each FCV fails "as is" on loss of hydraulic pressure at the hydraulic unit.

COMPLETION TIME 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months 12 hours FREQUENCY In accordance with the Surveillance Frequency Control Program (continued)

RIVER BEND 3.4-6 Amendment No. 84, 4-98, 196

SURVEILLANCE REQUIREMENTS continued SURVEILLANCE SR 3.4.2.2 Verify average rate of each FCV movement is:

FCVs 3.4.2 FREQUENCY

a.

11 % of stroke per second for opening; and In accordance with the Surveillance Frequency Control Program

b.

11 % of stroke per second for closing.

RIVER BEND 3.4-7 Amendment No. 84, 498, 196

SURVEILLANCE REQUIREMENTS SR 3.4.3.1 SURVEILLANCE

NC>TES-----------------------------

1.

Not required to be performed until 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after associated recirculation loop is in operation.

2.

Not required to be performed until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after> 23.8% RTP.

Verify at least two of the following criteria (a, b, and c) are satisfied for each operating recirculation loop:

a.

Recirculation loop drive flow versus flow control valve position differs by ::; 10% from established patterns.

b.

Recirculation loop drive flow versus total core flow differs by ::; 10% from established patterns.

c.

Each jet pump diffuser to lower plenum differential pressure differs by::; 20% from established patterns, or each jet pump flow differs by ::; 10% from established patterns.

Jet Pumps 3.4.3 FREQUENCY In accordance with the Surveillance Frequency Control Program RIVER BEND 3.4-9 Amendment No. 84, 444, 196

SURVEILLANCE REQUIREMENTS (continued)

SR 3.4.4.2 SR 3.4.4.3 SURVEILLANCE

N()TE-------------------------------

Valve actuation may be excluded.

Verify each required relief function S/RV actuates on an actual or simulated automatic initiation signal.

N()TE-------------------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reactor steam pressure and flow are adequate to perform the test.

Verify each required S/RV relief mode actuator strokes when manually actuated.

S/RVs 3.4.4 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the lnservice Testing Program on a STAGGERED TEST BASIS for each valve solenoid RIVER BEND 3.4-11 Amendment No. 81 130, 98, 196

ACTIONS (continued)

CONDITION C.

Required Action and associated Completion Time of Condition A or B not met.

OR Pressure boundary LEAKAGE exists.

SURVEILLANCE REQUIREMENTS REQUIRED ACTION C.1 Be in MODE 3.

C.2 Be in MODE 4.

SURVEILLANCE RCS Operational LEAKAGE 3.4.5 COMPLETION TIME 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 36 hours FREQUENCY SR 3.4.5.1 Verify RCS unidentified LEAKAGE, total LEAKAGE, In accordance with RIVER BEND and unidentified LEAKAGE increase are within limits.

the Surveillance Frequency Control Program 3.4-13 Amendment No. 84, 196

RCS Leakage Detection Instrumentation 3.4.7 SURVEILLANCE REQUIREMENTS SR 3.4.7.1 SR 3.4.7.2 SR 3.4.7.3 RIVER BEND SURVEILLANCE Perform CHANNEL CHECK of required drywell atmospheric monitoring system.

Perform CHANNEL FUNCTIONAL TEST of required leakage detection instrumentation.

Perform CHANNEL CALIBRATION of required leakage detection instrumentation.

FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program 3.4-19 Amendment No. 84, -WS, 196

SURVEILLANCE REQUIREMENTS SURVEILLANCE RCS Specific Activity 3.4.8 FREQUENCY SR 3.4.8.1

N()l"E---------------------------------

RIVER BEND

()nly required to be performed in MODE 1.

Verify reactor coolant D()SE EQUIVALENl" 1-131 specific activity is ~ 0.2 µCi/gm.

3.4-21 In accordance with the Surveillance Frequency Control Program Amendment No. 84, 196

RHR Shutdown Cooling System - Hot Shutdown 3.4.9 SURVEILLANCE REQUIREMENTS SR 3.4.9.1 SR 3.4.9.2 RIVER BEND SURVEILLANCE

N()TE---------------------------------

Not required to be met until 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months after reactor steam dome pressure is less than the RHR cut in permissive pressure.

Verify one RHR shutdown cooling subsystem or recirculation pump is operating.

N()TE---------------------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reactor steam dome pressure is less than the RHR cut in permissive pressure.

Verify RHR shutdown cooling subsystem locations susceptible to gas accumulation are sufficiently filled with water.

FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program 3.4-24 Amendment No. M, 488, 196

RHR Shutdown Cooling System - Cold Shutdown 3.4.10 ACTIONS (continued)

CONDITION REQUIRED ACTION B.

No RHR shutdown cooling B.1 Verify reactor coolant circulating by an alternate method.

subsystem in operation.

No recirculation pump in operation.

SURVEILLANCE REQUIREMENTS B.2 Monitor reactor coolant temperature and pressure.

SURVEILLANCE SR 3.4.10.1 Verify one RHR shutdown cooling subsystem or recirculation pump is operating.

COMPELETION TIME 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from discovery of no reactor coolant circulation Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter Once per hour FREQUENCY In accordance with the Surveillance Frequency Control Program SR 3.4.10.2 Verify RHR shutdown cooling subsystem locations susceptible to gas accumulation are sufficiently filled with water.

In accordance with the Surveillance Frequency Control Program RIVER BEND 3.4-26 Amendment No. 84, ~. 196

ACTIONS (continued)

CONDITION C.

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

Req u ired Action C.2 shall be completed if this Condition is entered.

REQUIRED ACTION C.1 Initiate action to restore parameter(s) to within limits.

RCS PIT Limits 3.4.11 COMPLETION TIME Immediately C.2 Determine RCS is acceptable Prior to entering Requirements of the LCO not met in other than MODES 1, 2, and 3.

for operation.

MODE 2 or 3 SURVEILLANCE REQUIREMENTS SR 3.4.11.1 SURVEILLANCE

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

Only required to be performed during RCS heatup and cooldown operations, and RCS inservice leak and hydrostatic testing.

Verify:

a.

RCS pressure and RCS temperature are within the limits of Figure 3.4.11-1,

b.

RCS heatup and cooldown rates are :s; 100°F in any one hour period for core not critical and core critical limits.

c.

RCS heatup and cooldown rates are :s; 20°F in any one hour period for inservice leak and hydrostatic testing limits.

FREQUENCY In accordance with the Surveillance Frequency Control Program (continued)

RIVER BEND 3.4-28 Amendment No. M, 444, 196

SURVEILLANCE REQUIREMENTS (continued)

SR 3.4.11.5 SR 3.4.11.6 SR 3.4.11.7 SURVEILLANCE

N()TE---------------------------------

Only required to be performed when tensioning the reactor vessel head bolting studs.

Verify reactor vessel flange and head flange temperatures are 2 70°F.

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

Not required to be performed until 30 minutes after RCS temperature ~ 80°F in M()DE 4.

Verify reactor vessel flange and head flange temperatures are 2 70°F.

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

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after RCS temperature ~ 100°F in MODE 4.

Verify reactor vessel flange and head flange temperatures are 2 70°F.

RCS PIT Limits 3.4.11 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued)

RIVER BEND 3.4-30 Amendment No. 84-, 196

3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.12 Reactor Steam Dome Pressure Reactor Steam Dome Pressure 3.4.12 LCO 3.4.12 The reactor steam dome pressure shall be ::; 1075 psig.

APPLICABILITY:

MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION A.

Reactor steam dome A.1 Restore reactor steam dome pressure not within limit.

pressure to within limit.

B.

Required Action and 8.1 Be in MODE 3.

associated Completion Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.4.12.1 Verify reactor steam dome pressure is::; 1075 psig.

COMPLETION TIME 15 minutes 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months FREQUENCY In accordance with the Surveillance Frequency Control Program RIVER BEND 3.4-33 Amendment No. 8-t, 444, 196

SURVEILLANCE REQUIREMENTS SR 3.5.1.1 SR 3.5.1.2 SR 3.5.1.3 SR 3.5.1.4 SURVEILLANCE Verify, for each ECCS injection/spray subsystem, locations susceptible to gas accumulation are sufficiently filled with water.

N()TE--------------------------------

1. Low pressure coolant injection (LPCI) subsystems may be considered ()PERABLE during alignment and operation for decay heat removal with reactor steam dome pressure less than the residual heat removal cut in permissive pressure in M()DE 3, if capable of being manually realigned and not otherwise inoperable.

2. Not required to be met for system vent flow paths opened under administrative control.

Verify each ECCS injection/spray subsystem manual, power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.

Verify ADS accumulator supply pressure is

~ 131 psig.

Verify each ECCS pump develops the specified flow rate with the specified pump differential pressure.

SYSTEM LPCS LPCI HPCS FL()W RATE

~ 5010 gpm

~ 5050 gpm

~ 5010 gpm PUMP DIFFERENTIAL PRESSURE

~ 282 psid

~ 102 psid

~ 415 psid ECCS -

Operating 3.5.1 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the lnservice Testing Program (continued)

RIVER BEND 3.5-4 Amendment No. 84, 4-M, 196

SURVEILLANCE REQUIREMENTS (continued)

SR 3.5.1.5 SR 3.5.1.6 SR 3.5.1.7 SURVEILLANCE

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

Vessel injection/spray may be excluded.

Verify each ECCS injection/spray subsystem actuates on an actual or simulated automatic initiation signal.

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

Valve actuation may be excluded.

Verify the ADS actuates on an actual or simulated automatic initiation signal.

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

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reactor steam pressure and flow are adequate to perform the test.

Verify each ADS valve relief mode actuator strokes when manually actuated.

ECCS -

Operating 3.5.1 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the lnservice Testing Program on a STAGGERED TEST BASIS for each valve solenoid (continued)

RIVER BEND 3.5-5 Amendment No. 81 130, 488, 196

SURVEILLANCE REQUIREMENTS continued SR 3.5.1.8 RIVER BEND SURVEILLANCE

N()TE-------------*----------------

ECCS actuation instrumentation is excluded.

Verify the ECCS RESP()NSE TIME for each ECCS injection/spray subsystem is within limits.

3.5-5a ECCS -

Operating 3.5.1 FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment No. 196

RPV Water Inventory Control 3.5.2 SURVEILLANCE REQUIREMENTS SR 3.5.2.1 SR 3.5.2.2 SR 3.5.2.3 SR 3.5.2.4 SR 3.5.2.5 RIVER BEND SURVEILLANCE Verify DRAIN TIME is~ 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

Verify, for a required low pressure ECCS injection/spray subsystem, the suppression pool water level is ~ 13 ft 3 inches.

Verify, for the required High Pressure Core Spray (HPCS) System, the:

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

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

Verify, for the required ECCS injection/spray subsystem, locations susceptible to gas accumulation are sufficiently filled with water.

N()TES-----------------------------

1. A low pressure coolant injection (LPCI) subsystem may be considered ()PERABLE during alignment and operation for decay heat removal, if capable of being manually realigned and not otherwise inoperable.

2. Not required to be met for system vent flow paths opened under administrative control.

Verify, for the required ECCS injection/spray subsystem, each manual, power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.

FREQUENCY In accordance with the Surveillance Frequency Control Program

In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) 3.5-8 Amendment No. 8+, 488, 4-W, 196

RPV Water Inventory Control 3.5.2 SURVEILLANCE REQUIREMENTS (continued)

SR 3.5.2.6 SR 3.5.2.7 SR 3.5.2.8 RIVER BEND SURVEILLANCE Operate the required ECCS injection/spray subsystem for~ 10 minutes.

Verify each valve credited for automatically isolating a penetration flow path actuates to the isolation position on an actual or simulated actuation signal.

---*-------------------------NOTE--------------------------------

Vessel injection/spray may be excluded.

Verify the required LPCI or LPCS subsystem actuates on a manual initiation signal, or the required HPCS subsystem can be manually operated.

FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program 3.5-9 Amendment No. 84, 4-eS, 4-W, 196

SURVEILLANCE REQUIREMENTS SR 3.5.3.1 SR 3.5.3.2 SR 3.5.3.3 SR 3.5.3.4 SURVEILLANCE Verify the RCIC System locations susceptible to gas accumulation are sufficiently filled with water.

N()TE--------------------------------

Not required to be met for system vent flow paths opened under administrative control.

Verify each RCIC System manual, power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.

N()TE--------------------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reactor steam pressure and flow are adequate to perform the test.

Verify, with RCIC steam supply pressure ~ 1075 psig and ~ 920 psig, the RCIC pump can develop a flow rate ~ 600 gpm against a system head corresponding to reactor pressure.

N()TE--------------------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reactor steam pressure and flow are adequate to perform the test.

Verify, with RCIC steam supply pressure ~ 165 psig and ~ 150 psig, the RCIC pump can develop a flow rate ~ 600 gpm against a system head corresponding to reactor pressure.

RCIC System 3.5.3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance.

Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued)

RIVER BEND 3.5-11 Amendment No. 81 114 168, ~. 196

SURVEILLANCE REQUIREMENTS continued SR 3.5.3.5 SURVEILLANCE

N()TE-------------------------------

Vessel injection may be excluded.

Verify the RCIC System actuates on an actual or simulated automatic initiation signal.

RCIC System 3.5.3 FREQUENCY In accordance with the Surveillance Frequency Control Program RIVER BEND 3.5-12 Amendment No. 84, 498, 196

Primary Containment Air Locks 3.6.1.2 SURVEILLANCE REQUIREMENTS SR 3.6.1.2.1 SR 3.6.1.2.2 SR 3.6.1.2.3 RIVER BEND SURVEILLANCE

N()TES-----------------------------

1.

An inoperable air lock door does not invalidate the previous successful performance of the overall air lock leakage test.

2.

Results shall be evaluated against acceptance criteria applicable to SR 3.6.1.1.1.

Perform required primary containment air lock leakage rate testing in accordance with the Primary Containment Leakage Rate Testing Program.

Verify primary containment air lock seal air flask pressure is ~ 90 psig.

N()TE-----------------------------

()nly required to be performed upon entry or exit through the primary containment air lock.

Verify only one door in the primary containment air lock can be opened at a time.

FREQUENCY In accordance with the Primary Containment Leakage Rate Testing Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) 3.6-7 Amendment No. 84--M, 4-32, 196

SURVEILLANCE REQUIREMENTS continued SR 3.6.1.2.4 SURVEILLANCE Verify, from an initial pressure of 90 psig, the primary containment air lock seal pneumatic system pressure does not decay at a rate equivalent to

> 1.50 psig for a period of 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

Primary Containment Air Locks 3.6.1.2 FREQUENCY In accordance with the Surveillance Frequency Control Program RIVER BEND 3.6-8 Amendment No. 81 132, 88, 196

SURVEILLANCE REQUIREMENTS SR 3.6.1.3.1 RIVER BEND SURVEILLANCE

N()TES-----------------------------

1.

Only required to be met in M()DES 1, 2, and 3.

2.

Not required to be met when the 36 inch primary containment purge valves are open for pressure control, ALARA or air quality considerations for personnel entry. Also, not required to be met during Surveillances, or special testing on the purge system that requires the valves to be open.

3.

If one Standby Gas Treatment (SGT) subsystem is in the primary containment purge flow path, both SGT subsystems must be ()PERABLE. In addition only one SGT subsystem may be operating in the primary containment purge flow path.

Verify each 36 inch primary containment purge valve is closed.

3.6-15 PCIVs 3.6.1.3 FREQUENCY In accordance with the Surveillance Frequency Control Program

( continued)

Amendment No. M, 196

SURVEILLANCE REQUIREMENTS continued SR 3.6.1.3.2 SURVEILLANCE

N()TES---------------------------

1.

Only required to be met in M()DES 1, 2, and

3.

2.

Valves and blind flanges in high radiation areas may be verified by use of administrative means.

3.

Not required to be met for PCIVs that are open under administrative controls.

Verify each primary containment isolation manual valve and blind flange that is located outside primary containment, drywall, and steam tunnel and is required to be closed during accident conditions is closed.

PCIVs 3.6.1.3 FREQUENCY In accordance with the Surveillance Frequency Control Program (continued)

RIVER BEND 3.6-16 Amendment No. 84, 44-e, 196

SURVEILLANCE REQUIREMENTS (continued)

SR 3.6.1.3.4 SR 3.6.1.3.5 SR 3.6.1.3.6 SR 3.6.1.3. 7 SURVEILLANCE Verify the isolation time of each power operated and each automatic PCIV, except MSIVs, is within limits.

N()TE-----------------------------

()nly required to be met in M()DES 1, 2, and 3.

Perform leakage rate testing for each primary containment purge valve with resilient seals.

Verify the isolation time of each MSIV is

?: 3 seconds and ::; 5 seconds.

Verify each automatic PCIV actuates to the isolation position on an actual or simulated isolation signal.

PCIVs 3.6.1.3 FREQUENCY In accordance with the lnservice Testing Program In accordance with the Primary Containment Leakage Rate Testing Program In accordance with the lnservice Testing Program In accordance with the Surveillance Frequency Control Program (continued)

RIVER BEND 3.6-17 Amendment No. 81 152,408, 196

SURVEILLANCE REQUIREMENTS (continued)

SR 3.6.1.3.8 SR 3.6.1.3.9 SURVEILLANCE Verify in-leakage rate of s 340 scfh for each of the following valve groups when tested at 11.5 psid for MS-PLCS valves.

a.

Division I MS-PLCS valves

b.

Division 11 MS-PLCS valves

N()TE-----------------------------

Only required to be met in MODES 1, 2, and 3.

Verify the combined leakage rate for all secondary containment bypass leakage paths is s 580,000 cc/hr when pressurized to~ Pa.

PCIVs 3.6.1.3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Primary Containment Leakage Rate Testing Program (continued)

RIVER BEND 3.6-18 Amendment No. 81 84 Q8 132, 498, 196

Primary Containment Pressure 3.6.1.4 3.6 CONTAINMENT SYSTEMS 3.6.1.4 Primary Containment Pressure LCO 3.6.1.4 Primary containment pressure shall be 2 -0.3 psig and ~ 0.3 psig.

APPLICABILITY:

MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION A.

Primary containment A.1 Restore primary pressure not within limits.

containment pressure to within limits.

B.

Required Action and B.1 Be in MODE 3.

associated Completion Time not met.

AND B.2 Be in MODE 4.

SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.6.1.4.1 RIVER BEND Verify primary containment pressure is within limits.

3.6-21 COMPLETION TIME 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months 12 hours 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment No. 84, 196

Primary Containment Air Temperature 3.6.1.5 3.6 CONTAINMENT SYSTEMS 3.6.1.5 Primary Containment Air Temperature LCO 3.6.1.5 Primary containment average air temperature shall be ::;; 90°F.

APPLICABILITY:

MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION A.

Primary containment A.1 Restore primary average air temperature containment average air not within limit.

temperature to within limit.

B.

Required Action and 8.1 Be in MODE 3.

associated Completion Time not met.

AND 8.2 Be in MODE 4.

SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.6.1.5.1 RIVER BEND Verify primary containment average air temperature is within limit.

3.6-22 COMPLETION TIME 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months 12 hours 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment No. 84, 196

SURVEILLANCE REQUIREMENTS SR 3.6.1.6.1 SR 3.6.1.6.2 SURVEILLANCE

N()TE------------------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reactor steam pressure and flow are adequate to perform the test.

Verify each LLS valve relief mode actuator strokes when manually actuated.

N()TE-----------------------------

Valve actuation may be excluded.

Verify the LLS System actuates on an actual or simulated automatic initiation signal.

LLS Valves 3.6.1.6 FREQUENCY In accordance with the lnservice Testing Program on a STAGGERED TEST BASIS for each valve solenoid In accordance with the Surveillance Frequency Control Program RIVER BEND 3.6-24 Amendment No. 81 130, ~. 196

Primary Containment Unit Coolers 3.6.1.7 SURVEILLANCE REQUIREMENTS SR 3.6.1.7.1 SR 3.6.1.7.2 SR 3.6.1.7.3 RIVER BEND SURVEILLANCE Verify each required primary containment unit cooler pressure relief and backdraft damper in the flow path that is not locked, sealed, or otherwise secured in position, is in the correct position.

Verify each required primary containment unit cooler develops a flow rate of~ 50,000 cfm on recirculation flow through the unit cooler.

Verify each required primary containment unit cooler actuates throughout its emergency operating sequence on an actual or simulated automatic initiation signal.

FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program 3.6-26 Amendment No. 84-, 488, 196

3.6 CONTAINMENT SYSTEMS 3.6.1.9 Main Steam-Positive Leakage Control System (MS-PLCS)

LCO 3.6.1.9 Two MS-PLCS subsystems shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION A.

One MS-PLCS subsystem A.1 Restore MS-PLCS inoperable.

subsystem to OPERABLE status.

B.

Two MS-PLCS B.1 Restore one MS-PLCS subsystems inoperable.

subsystem to OPERABLE status.

C.

Required Action and C. 1

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

associated Completion LCO 3.0.4.a is not Time not met.

applicable when entering MODE 3.

Be in MODE 3.

SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.6.1.9.1 Verify air pressure in each associated PVLCS subsystem is 2'. 101 psig.

MS-PLCS 3.6.1.9 COMPLETION TIME 30 days 7 days 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months FREQUENCY In accordance with the Surveillance Frequency Control Program (continued)

RIVER BEND 3.6-29 Amendment No. 84, 48a, 196

SURVEILLANCE REQUIREMENTS (continued)

SR 3.6.1.9.2 SR 3.6.1.9.3 SURVEILLANCE Operate each PVLCS compressor ~ 15 minutes.

Perform a system functional test of each MS-PLCS subsystem.

MS-PLCS 3.6.1.9 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program RIVER BEND 3.6-30 Amendment No. 84, 498, 196

Primary Containment-Shutdown 3.6.1.10 SURVEILLANCE REQUIREMENTS SR 3.6.1.10.1 RIVER BEND SURVEILLANCE

N()TE------------------------------

Not required to be met for vent and drain line pathways provided the total calculated flow rate through open vent and drain pathways is ::;; 70.2 cfm.

Verify each penetration flow path, required to be closed during accident conditions, is closed.

3.6-32 FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment No. 84, 196

Suppression Pool Average Temperature 3.6.2.1 SURVEILLANCE REQUIREMENTS SR 3.6.2.1.1 RIVER BEND SURVEILLANCE Verify suppression pool average temperature is within the applicable limits.

3.6-35 FREQUENCY In accordance with the Surveillance Frequency Control Program 5 minutes when performing testing that adds heat to the suppression pool Amendment No. 84, 196

3.6 CONTAINMENT SYSTEMS 3.6.2.2 Suppression Pool Water Level Suppression Pool Water Level 3.6.2.2 LCO 3.6.2.2 Suppression pool water level shall be ;?: 19 ft 6 inches and :::;; 20 ft O inches.

APPLICABILITY:

MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

Suppression pool water A.1 Restore suppression 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months level not within limits.

pool water level to within limits.

B.

Required Action and B.1 Be in MODE 3.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met.

AND B.2 Be in MODE 4.

36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.2.1 Verify suppression pool water level is within limits.

In accordance with the Surveillance Frequency Control Program RIVER BEND 3.6-36 Amendment No. 84, 196

RHR Suppression Pool Cooling 3.6.2.3 SURVEILLANCE REQUIREMENTS SR 3.6.2.3.1 SR 3.6.2.3.2 SR 3.6.2.3.3 RIVER BEND SURVEILLANCE Verify each RHR suppression pool cooling subsystem manual, power operated, and automatic valve in the flow path that is not locked, sealed, or otherwise secured in position is in the correct position or can be aligned to the correct position.

Verify RHR suppression pool cooling subsystem locations susceptible to gas accumulation are sufficiently filled with water.

Verify each RHR pump develops a flow rate 2 5050 gpm through the associated heat exchangers to the suppression pool.

FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the lnservice Testing Program 3.6-38 Amendment No. 84, 488, 196

Primary Containment and Drywall Hydrogen lgniters 3.6.3.2 ACTIONS (continued)

CONDITION REQUIRED ACTION C.

Required Action and associated Completion Time not met.

C.1 Be in MODE 3.

SURVEILLANCE REQUIREMENTS SR 3.6.3.2.1 SR 3.6.3.2.2 SR 3.6.3.2.3 SURVEILLANCE Energize each primary containment and drywall hydrogen igniter division and perform current versus voltage measurements to verify required igniters in service.

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

Not required to be performed until 92 days after discovery of four or more igniters in the division inoperable.

Energize each primary containment and drywall hydrogen igniter division and perform current versus voltage measurements to verify required igniters in service.

Verify each required igniter in inaccessible areas develops sufficient current draw for a 2 1700°F surface temperature.

COMPLETION TIME 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued)

RIVER BEND 3.6-42 Amendment No. M, 468, 196

Primary Containment and Drywall Hydrogen lgniters 3.6.3.2 SURVEILLANCE REQUIREMENTS continued SR 3.6.3.2.4 RIVER BEND SURVEILLANCE Verify each required igniter in accessible areas develops a surface temperature of~ 1700°F.

FREQUENCY In accordance with the Surveillance Frequency Control Program 3.6-43 Amendment No. 84, 4-68, 196

Primary Containment/Drywell Hydrogen Mixing System 3.6.3.3 ACTIONS (continued)

CONDITION C.

Required Action and associated Completion Time not met.

SURVEILLANCE REQUIREMENTS REQUIRED ACTION C.1 Be in MODE 3.

SURVEILLANCE SR 3.6.3.3.1 SR 3.6.3.3.2 Operate each primary containment/drywell hydrogen mixing subsystem for 2 15 minutes.

Verify each primary containment/drywell hydrogen mixing subsystem flow rate is 2 600 cfm.

COMPLETION TIME 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months FREQUENCY Every COLD SHUTDOWN, if not performed within the previous 92 days.

In accordance with the Surveillance Frequency Control Program RIVER BEND 3.6-45 Amendment No. 84--89, ~. 196

3.6 CONTAINMENT SYSTEMS 3.6.4.1 Secondary Containment-Operating Secondary Containment-Operating 3.6.4.1 LCO 3.6.4.1 The shield building and auxiliary building shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

Secondary containment A.1 Restore secondary 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months inoperable.

containment to OPERABLE status.

B.

Required Action and B.1

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

associated Completion LCO 3.0.4.a is not Time not met.

applicable when entering MODE 3.

Be in MODE 3.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEILLANCE REQUIREMENTS SR 3.6.4.1.1 SURVEILLANCE Verify shield building annulus and auxiliary building vacuum is ~ 3.0 and ~ 0.0 inch of vacuum water gauge, respectively.

FREQUENCY In accordance with the Surveillance Frequency Control Program (continued)

RIVER BEND 3.6-46 Amendment No. 84, 44-J, 4-Sa, 196

Secondary Containment-Operating 3.6A.1 SURVEILLANCE REQUIREMENTS (continued)

SR 3.6.4.1.2 SR 3.6.4.1.3 SR 3.6.4.1.4 SR 3.6.4.1.5 SR 3.6.4.1.6 RIVER BEND SURVEILLANCE Verify all secondary containment equipment hatches are closed and sealed and loop seals filled.

Verify each secondary containment access door is closed, except when the access opening is being used for entry and exit.

Verify each standby gas treatment (SGT) subsystem will draw down the shield building annulus and auxiliary building to 2 0.5 and 2 0.25 inch of vacuum water gauge in~ 18.5 and

~ 34.5 seconds, respectively.

Deleted Verify each SGT subsystem can maintain 2 0.5 and 2 0.25 inch of vacuum water gauge in the shield building annulus and auxiliary building, respectively, for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Not Applicable In accordance with the Surveillance Frequency Control Program 3.6-47 Amendment No. 81 95 113 132, e8, 196

SURVEILLANCE REQUIREMENTS SR 3.6.4.2.1 SR 3.6.4.2.2 SURVEILLANCE Verify the isolation time of each required power operated automatic SCID and FBID is within limits.

Verify each required automatic SCID and FBID actuates to the isolation position on an actual or simulated automatic isolation signal.

SCIDs/FBIDs 3.6.4.2 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program RIVER BEND 3.6-50 Amendment No. 81 95 113, 498, 196

SURVEILLANCE REQUIREMENTS SR 3.6.4.3.1 SR 3.6.4.3.2 SR 3.6.4.3.3 SR 3.6.4.3.4 SURVEILLANCE Operate each SGT subsystem for ~ 15 continuous minutes.

Perform required SGT filter testing in accordance with the Ventilation Filter Testing Program (VFTP).

Verify each SGT subsystem actuates on an actual or simulated initiation signal.

Verify each SGT filter cooling bypass damper can be opened and the fan started.

SGT System 3;6.4.3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the VFTP In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program RIVER BEND 3.6-52 Amendment No. 84, 498, ~. 196

3.6 CONTAINMENT SYSTEMS 3.6.4.5 Fuel Building LCO 3.6.4.5 The fuel building shall be OPERABLE.

Fuel Building 3.6.4.5 APPLICABILITY:

During movement of recently irradiated fuel assemblies in the fuel building.

ACTIONS

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

LCO 3.0.3 is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A.

Fuel building inoperable.

A.1 Suspend movement of Immediately recently irradiated fuel assemblies in the fuel building.

SURVEILLANCE REQUIREMENTS SR 3.6.4.5.1 SR 3.6.4.5.2 SR 3.6.4.5.3 RIVER BEND SURVEILLANCE Verify fuel building vacuum is 2'. 0.25 inch of vacuum water gauge.

Verify all fuel building equipment hatch covers are installed.

Verify each fuel building access door is closed, except when the access opening is being used for entry and exit.

FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program 3.6-55 Amendment No. 84-9&, 44-J, 196

Fuel Building Ventilation System-Fuel Handling 3.6.4.7 SURVEILLANCE REQUIREMENTS SR 3.6.4.7.1 SR 3.6.4.7.2 SR 3.6.4.7.3 SR 3.6.4.7.4 SR 3.6.4.7.5 RIVER BEND SURVEILLANCE Verify one fuel building ventilation charcoal filtration subsystem in operation.

Operate each fuel building ventilation charcoal filtration subsystem for 2'. 15 continuous minutes.

Perform fuel building ventilation charcoal filtration filter testing in accordance with the Ventilation Filter Testing Program (VFTP).

Verify each fuel building ventilation charcoal filtration subsystem actuates on an actual or simulated initiation signal.

Verify each fuel building ventilation charcoal filtration filter cooling bypass damper can be opened and the fan started.

FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the VFTP In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program 3.6-59 Amendment No. 84, 498, ~. 196

3.6 CONTAINMENT SYSTEMS 3.6.5.1 Drywell LCO 3.6.5.1 The drywell shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION A.

Drywell inoperable.

A.1 Restore drywell to OPERABLE status.

B.

Required Action and 8.1 Be in MODE 3.

associated Completion Time not met.

AND 8.2 Be in MODE 4.

SURVEILLANCE REQUIREMENTS SR 3.6.5.1.1 SR 3.6.5.1.2 SURVEILLANCE Verify personnel door inflatable seal air flask pressure ~ 75 psig.

Verify from an initial pressure of 75 psig, the personnel door inflatable seal pneumatic system pressure does not decay at a rate equivalent to

~ 20.0 psig for a period of 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

Drywell 3.6.5.1 COMPLETION TIME 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months 12 hours 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued)

RIVER BEND 3.6-60 Amendment No. 81 132,498, 196

SURVEILLANCE REQUIREMENTS continued SR 3.6.5.1.3 SURVEILLANCE Verify bypass leakage is less than or equal to the bypass leakage limit.

However, during the first unit startup following bypass leakage testing performed in accordance with this SR, the acceptance criterion is s 10% of the drywell bypass leakage limit.

Drywell 3.6.5.1 FREQUENCY

N()TE-------

SR 3.0.2 is not applicable for extensions > 9 months 24 months following 2 consecutive tests with bypass leakage greater than the bypass leakage limit until 2 consecutive tests are less than or equal to the bypass leakage limit 48 months following a test with bypass leakage greater than the bypass leakage limit In accordance with the Surveillance Frequency Control Program RIVER BEND 3.6-61 Amendment No. 8187144, 494, 196

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE SR 3.6.5.1.4 Visually inspect the exposed accessible interior and exterior surfaces of the drywell.

SR 3.6.5.1.5 Verify seal leakage rate when the gap between the door seals is pressurized to~ 3 psid.

SR 3.6.5.1.6 Verify drywell air lock leakage by performing an air lock barrel leakage test at~ 3 psid.

Drywell 3.6.5.1 FREQUENCY Once prior to performance of each Type A test required by SR 3.6.1.1.1 Once within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months after each drywell air lock door closing In accordance with the Surveillance Frequency Control Program RIVER BEND 3.6-62 Amendment No. 84, 31, 196

SURVEILLANCE REQUIREMENTS SR 3.6.5.2.1 SR 3.6.5.2.2 SR 3.6.5.2.3 SR 3.6.5.2.4 SR 3.6.5.2.5 SURVEILLANCE Deleted Verify drywell air lock seal air flask pressure is

~ 75 psig.

N()TE------------------------------

()nly required to be performed upon entry into drywell.

Verify only one door in the drywell air lock can be opened at a time.

Deleted Verify, from an initial pressure of 75 psig, the drywell air lock seal pneumatic system pressure does not decay at a rate equivalent to> 20.0 psig for a period of 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

Drywell Air Lock 3.6.5.2 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program RIVER BEND 3.6-66 Amendment No. 81 87 132, 498, 196

Drywell Isolation Valves 3.6.5.3 SURVEILLANCE REQUIREMENTS SR 3.6.5.3.1 SR 3.6.5.3.2 SR 3.6.5.3.3 RIVER BEND SURVEILLANCE Verify each 24 inch drywell purge isolation valve is sealed closed.

N()TE-------------------------------

Not required to be met when the primary containmenUdrywell hydrogen mixing inlet or outlet valves are open for pressure control.

Verify each primary containmenUdrywell hydrogen mixing isolation valve is closed.

N()TES----------------------------

1.

Valves and blind flanges in high radiation areas may be verified by use of administrative means.

2.

Not required to be met for drywell isolation valves that are open under administrative controls.

Verify each drywell isolation manual valve and blind flange that is required to be closed during accident conditions is closed.

FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Prior to entering M()DE 2 or 3 from M()DE 4, if not performed in the previous 92 days (continued) 3.6-69 Amendment No. 84, 89, 196

Drywall Isolation Valves 3.6.5.3 SURVEILLANCE REQUIREMENTS (continued)

SR 3.6.5.3.4 SR 3.6.5.3.5 SR 3.6.5.3.6 RIVER BEND SURVEILLANCE Verify the isolation time of each power operated and each automatic drywall isolation valve is within limits.

Verify each automatic drywall isolation valve actuates to the isolation position on an actual or simulated isolation signal.

Verify the cumulative time that the primary containment/drywall hydrogen mixing inlet or outlet penetrations are open to be ~ 5 hours5.787037e-5 days 0.00139 hours 8.267196e-6 weeks 1.9025e-6 months per 365 days in Modes 1 and 2, and ~ 90 hours0.00104 days 0.025 hours 1.488095e-4 weeks 3.4245e-5 months per 365 days in Mode 3.

FREQUENCY In accordance with the lnservice Testing Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program 3.6-70 Amendment No. 84-,gg, 4-68, 196

3.6 CONTAINMENT SYSTEMS 3.6.5.4 Drywell Pressure Drywell Pressure 3.6.5.4 LCO 3.6.5.4 Drywell-to-primary containment differential pressure shall be ~ -0.3 psid and::;; 1.2 psid.

APPLICABILITY:

MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION A.

Drywell-to-primary A.1 Restore drywell-to-containment differential primary containment pressure not within limits.

differential pressure to within limits.

B.

Required Action and B.1 Be in MODE 3.

associated Completion Time not met.

AND B.2 Be in MODE 4.

SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.6.5.4.1 RIVER BEND Verify drywell-to-primary containment differential pressure is within limits.

3.6-71 COMPLETION TIME 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months 12 hours 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment No. 84-, 196

3.6 CONTAINMENT SYSTEMS 3.6.5.5 Drywell Air Temperature LCO 3.6.5.5 Drywell average air temperature shall be:::; 145°F.

APPLICABILITY:

MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION A.

Drywell average air A.1 Restore drywell average temperature not within air temperature to within limit.

limit.

B.

Required Action and 8.1 Be in MODE 3.

associated Completion Time not met.

AND 8.2 Be in MODE 4.

SURVEILLANCE REQUIREMENTS SURVEILLANCE Drywell Air Temperature 3.6.5.5 COMPLETION TIME 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months 12 hours 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months FREQUENCY SR 3.6.5.5.1 Verify drywell average air temperature is within In accordance with RIVER BEND limit.

the Surveillance Frequency Control Program 3.6-72 Amendment No. 8-1-, 196

ACTIONS (continued)

CONDITION REQUIRED ACTION H.

Required Action and H.1 ----------NOTE-----------

associated Completion LCO 3.0.4.a is not Time of Condition A, E, or applicable when G not met.

entering MODE 3.

Be in MODE 3.

I.

Required Action and 1.1 Be in MODE 3.

associated Completion Time of Condition B, D or AND F not met.

1.2 Be in MODE 4.

OR Both SSW subsystems inoperable for reasons other than Condition F.

OR Three or four UHS cooling tower fan cells inoperable.

SURVEILLANCE REQUIREMENTS SR 3.7.1.1 SR 3.7.1.2 SURVEILLANCE Verify the water level of UHS cooling tower basin is

~78%.

Verify the average water temperature of UHS is

s; 88°F.

SSW System and UHS 3.7.1 COMPLETION TIME 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 12 hours 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued)

RIVER BEND 3.7-3 Amendment No. 84 486, 196

SURVEILLANCE REQUIREMENTS (continued)

SR 3.7.1.3 SR 3.7.1.4 SR 3.7.1.5 SURVEILLANCE Operate each cooling tower fan cell for ~ 15 minutes.

Verify each required SSW subsystem manual, power operated, and automatic valve in the flow path servicing safety related systems or components, that is not locked, sealed, or otherwise secured in position, is in the correct position.

Verify each SSW subsystem actuates on an actual or simulated initiation signal.

SSW System and UHS 3.7.1 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program RIVER BEND 3.7-4 Amendment No. 84, 498, 196

ACTIONS (continued)

CRFA System 3.7.2 CONDITION REQUIRED ACTION COMPLETION TIME F. Two CRFA subsystems inoperable during movement of recently irradiated fuel assemblies in the primary containment or fuel building.

F.1 Suspend movement of recently Immediately OR One or more CRFA subsystems inoperable due to inoperable CRE boundary during movement of recently irradiated fuel assemblies in the primary containment or fuel building.

SURVEILLANCE REQUIREMENTS irradiated fuel assemblies in the primary containment and fuel building.

SURVEILLANCE SR 3.7.2.1 SR 3.7.2.2 SR 3.7.2.3 Operate each CRFA subsystem for~ 15 continuous minutes.

Perform required CRFA filter testing in accordance with the Ventilation Filter Testing Program (VFTP).

Verify each CRFA subsystem actuates on an actual or simulated initiation signal.

FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the VFTP In accordance with the Surveillance Frequency Control Program (continued)

RIVER BEND 3.7-7 Amendment No. 81119 132154 165 4e8,-1-8J,4W, 196

ACTIONS (continued)

CONDITION Control Room AC System 3.7.3 REQUIRED ACTION COMPLETION TIME E. Required Action and associated Completion Time of Condition B not met during movement of recently irradiated fuel assemblies in the primary containment or fuel building.

E.1 Suspend movement of recently Immediately irradiated fuel assemblies in the primary containment and fuel building.

SURVEILLANCE REQUIREMENTS SR 3.7.3.1 RIVER BEND SURVEILLANCE Verify each control room AC subsystem has the capability to remove the assumed heat load.

FREQUENCY In accordance with the Surveillance Frequency Control Program 3.7-11 Amendment No. 81 119 132, 498 93, 196

SURVEILLANCE REQUIREMENTS SR 3.7.4.1 SR 3.7.4.2 SURVEILLANCE Verify the gross gamma activity rate of the noble gases is ::s; 290 mCi/second after decay of 30 minutes.

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

Not required to be performed until 31 days after any main steam line not isolated and SJAE in operation.

.L---------------------------------------------------------

Verify the gross gamma activity rate of the noble gases is ::s; 290 mCi/second after decay of 30 minutes.

Main Condenser Offgas 3.7.4 FREQUENCY Once within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after a

~ 50% increase in the nominal steady state fission gas release rate after factoring out increases due to changes in THERMAL POWER level In accordance with the Surveillance Frequency Control Program RIVER BEND 3.7-13 Amendment No. 84, 196

Main Turbine Bypass System 3.7.5 SURVEILLANCE REQUIREMENTS SR 3.7.5.1 SR 3.7.5.2 SR 3.7.5.3 RIVER BEND SURVEILLANCE Verify one complete cycle of each main turbine bypass valve.

Perform a system functional test.

Verify the TURBINE BYPASS SYSTEM RESPONSE TIME is within limits.

FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program 3.7-14a Amendment No. 81 114 ma, 498, 196

3. 7 PLANT SYSTEMS 3.7.6 Fuel Pool Water Level Fuel Pool Water Level 3.7.6 LCO 3.7.6 The fuel pool water level shall be~ 23 ft over the top of irradiated fuel assemblies seated in the spent fuel storage pool and upper containment fuel storage pool racks.

APPLICABILITY:

During movement of irradiated fuel assemblies in the associated fuel storage pool.

ACTIONS CONDITION REQUIRED ACTION A.

Fuel pool water level not within limit.

A.1 ------------NOTE-----------

LCO 3.0.3 is not applicable.

Suspend movement of irradiated fuel assemblies in the associated fuel storage pool(s).

SURVEILLANCE REQUIREMENTS SR 3.7.6.1 RIVER BEND

SURVEILLANCE Verify the fuel pool water level is ~ 23 ft over the top of irradiated fuel assemblies seated in the storage racks.

3.7-15 COMPLETION TIME Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment No. M, 196

SURVEILLANCE REQUIREMENTS SR 3.8.1.1 SR 3.8.1.2 SURVEILLANCE Verify correct breaker alignment and indicated power availability for each required offsite circuit.

~--------------N()TES----------------~---------~---

1.

Performance of SR 3.8.1.7 satisfies this SR.

2.

All DG starts may be preceded by an engine prelube period and followed by a warm up period prior to loading.

3.

A modified DG start involving gradual acceleration to synchronous speed may be used for this SR as recommended by the manufacturer. When modified start procedures are not used, the time, voltage, and frequency tolerances of SR 3.8.1. 7 must be met.

Verify each DG starts from standby conditions and achieves:

a.

For DG 1A and DG 1 B, steady state voltage 2:: 37 40 V and s 4368 V and frequency 2:: 58.8 Hz ands 60.2 Hz.

b.

For DG 1C:

1.

Maximum of 5400 V, and 66. 75 Hz, and

2.

Steady state voltage 2:: 37 40 V and s 4580 V and frequency 2:: 58.8 Hz and s60.2 Hz.

AC Sources-Operating 3.8.1 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued)

RIVER BEND 3.8-5 Amendment No. 8190121, 437, 196

SURVEILLANCE REQUIREMENTS (continued)

SR 3.8.1.3 SR 3.8.1.4 SR 3.8.1.5 SR 3.8.1.6 SURVEILLANCE

~-------~------------NOTES-~-----~-------~-----------

1.

DG loadings may include gradual loading as recommended by the manufacturer.

2.

Momentary transients outside the load range do not invalidate this test.

3.

This Surveillance shall be conducted on only one DG at a time.

4.

This SR shall be preceded by, and immediately follow, without shutdown, a successful performance of SR 3.8.1.2 or SR 3.8.1. 7 Verify each DG operates for 2::: 60 minutes at a load 2::: 3050 kW and :s;; 3100 kW for DG 1A and DG 1 B, and 2::: 2525 kW and :s;; 2600 kW for DG 1 C.

Verify each day tank contains 2::: 316.3 gal of fuel oil.

Check for and remove accumulated water from each day tank.

Verify the fuel oil transfer system operates to automatically transfer fuel oil from the storage tank to the day tank.

AC Sources-Operating 3.8.1 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued)

RIVER BEND 3.8-6 Amendment No. 8190121, 487, 196

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS continued SR 3.8.1.7 RIVER BEND SURVEILLANCE

~----~-----~---NOTE------------------------~--------~-

AII DG starts may be preceded by an engine prelube period.

Verify each DG starts from standby conditions and achieves:

a.

For DG 1A and DG 1 B:

1.

In :'.S: 10 seconds, voltage 2 37 40 V and frequency 2 58.8 Hz; and

2.

Steady state voltage 2 37 40 V and

'.S: 4368 V and frequency 2 58.8 Hz and

'.S: 60.2 Hz.

b.

For DG 1C:

1.

Maximum of 5400 V, and 66. 75 Hz, and

2.

In :'.S: 13 seconds, voltage 2 37 40 V and frequency 2 58.8 Hz; and

3.

Steady state voltage 2 3740 V and

'.S: 4580 V and frequency 2 58.8 Hz and

'.S: 60.2 Hz.

FREQUENCY In accordance with the Surveillance Frequency Control Program (continued) 3.8-7 Amendment No. 81 121 165 168 4+-e,4-37, 196

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SR 3.8.1.8 SR 3.8.1.9 RIVER BEND SURVEILLANCE

N()l"ES------------------------------

1.

This Surveillance shall not be performed in M()DE 1 or 2. However, credit may be taken for unplanned events that satisfy this SR.

2.

SR 3.8.1.8.b is only required to be met if 22 kV onsite circuit is supplying Division Ill safety related bus E22-S004 from normal power transformer STX-XNS 1 C.

Verify, for required unit power supplies:

a.

Manual transfer of unit power supply from the normal offsite circuit to required alternate offsite circuit; and

b.

Automatic transfer of bus E22-S004 through NNS-SWG1A or NNS-SWG1 B from the 22 kV onsite circuit to required offsite circuit.

N()TE--------------------------------

1.

Credit may be taken for unplanned events that satisfy this SR.

2.

If performed with DG synchronized with offsite power, it shall be performed at a power factor

0.9 Verify each DG rejects a load greater than or equal to its associated single largest post accident load and following load rejection, the engine speed is maintained less than nominal plus 75% of the difference between nominal speed and the overspeed trip setpoint or 15% above nominal, whichever is lower.

FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program

( continued) 3.8-8 Amendment No. 81 121 133 137 498,4-37, 196

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SR 3.8.1.10 SR 3.8.1.11 RIVER BEND SURVEILLANCE

~---------------N()TE~----~-----------------------

Credit may be taken for unplanned events that satisfy this SR Verify each DG operating at a power factor~ 0.9 does not trip and voltage is maintained~ 4784 V for DG 1A and DG 1 B and ~ 5400 V for DG 1 C during and following a load rejection of a load ~ 3050 kW and

~ 3130 kW for DGs 1A and 1 Band~ 2525 kW and

~ 2600 kW for DG 1 C.

~----------------N()TES-------------------~-----

1.

All DG starts may be preceded by an engine prelube period.

2.

This Surveillance shall not be performed in M()DE 1, 2, or 3. (Not applicable to DG 1 C)

However, credit may be taken for unplanned events that satisfy this SR Verify on an actual or simulated loss of offsite power signal:

a.

De-energization of emergency buses;

b.

Load shedding from emergency buses for Divisions I and II; and FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program

( continued) 3.8-9 Amendment No. 81 121 133 168 37, 196

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.11

( continued)

RIVER BEND

c.

DG auto-starts from standby condition and:

1.

energizes permanently connected loads in s 10 seconds for DG 1 A and DG 1 B and s 13 seconds for DG 1 C,

2.

energizes auto-connected shutdown loads,

3.

maintains steady state voltage

i. for DG 1A and DG 1B:?: 3740 Vand s 4368 V, ii. for DG 1C:?: 3740 V ands 4580 V

4.

maintains steady state frequency ~ 58.8 Hz ands 60.2 Hz, and

5.

supplies permanently connected and auto-connected shutdown loads for

~ 5 minutes.

( continued) 3.8-10 Amendment No. 81 121 133 165

-WS,4fil'., 196

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SR 3.8.1.12 RIVER BEND SURVEILLANCE

~----~---NOTES-~-----~-------~-----~--

1.

All DG starts may be preceded by an engine prelube period.

2.

This Surveillance shall not be performed in MODE 1 or 2. (Not applicable to DG 1 C)

However, credit may be taken for unplanned events that satisfy this SR.

Verify on an actual or simulated Emergency Core Cooling System (ECCS) initiation signal each DG auto-starts from standby condition and:

a.

For DG 1 C during the auto-start maintains voltage ::; 5400 V and frequency ::; 66. 75 Hz;

b.

In::; 10 seconds for DG 1A and DG 1B and

13 seconds for DG 1 C after auto-start and during tests, achieves voltage 2: : 37 40 V and frequency 2:: 58.8 Hz.

c.

Achieves steady state voltage

1.

For DG 1 A and DG 1 B 2:: 37 40 V and

4368 V,

2.

For DG 1C 2:: 3740 Vand::; 4580 V, and

3.

For DG 1 A, 1 B, and 1 C, frequency of 2:: 58.8 and ::; 60.2 Hz; and

d.

Operates for 2:: 5 minutes.

FREQUENCY In accordance with the Surveillance Frequency Control Program (continued) 3.8-11 Amendment No. 81 94 121 ma 168, 87, 196

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SR 3.8.1.13 SR 3.8.1.14 RIVER BEND SURVEILLANCE

N()TE----------------~---------------

This Surveillance shall not be performed in MODE 1, 2, or 3. (Not applicable to DG 1 C) However, credit may be taken for unplanned events that satisfy this SR.

Verify each DG's automatic trips are bypassed on an actual or simulated ECCS initiation signal except:

a.

Engine overspeed; and

b.

Generator differential current.

~---------------N()TES---------------------~--------

1.

Momentary transients outside the load and power factor ranges do not invalidate this test.

2.

Credit may be taken for unplanned events that satisfy this SR Verify each DG operating at a power factors 0.9, operates for 2 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months s:

a.

For DG 1A and DG 18 loaded 2 3050 kW and s 3130 kW; and

b.

For DG 1C:

1.

For 2 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months loaded 2 2750 kW and s 2850 kW, and

2.

For the remaining hours of the test loaded 2 2525 kW ands 2600 kW.

FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) 3.8-12 Amendment No. 81 121 133 165

~. 8-7, 196

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SR 3.8.1.15 RIVER BEND SURVEILLANCE

~-----------------NOTES-------------------~----------

1.

This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated ~ 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months loaded ~ 3050 kW and s 3100 kW for DG 1A and DG 18, and

~ 2525 kW and s 2600 for DG 1 C, or operating temperatures have stabilized, which ever is longer.

Momentary transients outside of the load range do not invalidate this test.

2.

All DG starts may be preceded by an engine prelube period.

Verify each DG starts and achieves:

1.

In s 10 seconds for DG 1A and DG 1 Band s 13 seconds for DG 1 C voltage ~ 37 40 V and frequency~ 58.8 Hz, and

2.

Steady state voltage a)

For DG 1A and DG 18 ~ 3740 Vand s 4368 V b) For DG 1C ~ 3740 Vand s 4580 Vand c) For DG 1A, 18, and 1C frequency

~ 58.8 Hz and s 60.2 Hz.

FREQUENCY In accordance with the Surveillance Frequency Control Program (continued) 3.8-13 Amendment No. 81 95 121 133

-W8,-1-8+, 196

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SR 3.8.1.16 SR 3.8.1.17 SR 3.8.1.18 RIVER BEND SURVEILLANCE

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

This Surveillance shall not be performed in MODE 1, 2, or 3. (Not applicable to DG 1 C) However, credit may be taken for unplanned events.that satisfy this SR.

Verify each DG:

a.

Synchronizes with offsite power source while loaded with emergency loads upon a simulated restoration of offsite power;

b.

Transfers loads to offsite power source; and

c.

Returns to ready-to-load operation.

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

This Surveillance shall not be performed in MODE 1, 2, or 3. (Not applicable to DG 1 C) However, credit may be taken for unplanned events that satisfy this SR.

Verify, with a DG operating in test mode and connected to its bus, an actual or simulated ECCS initiation signal overrides the test mode by:

a.

Returning DG to ready-to-load operation; and

b.

Automatically energizing the emergency loads from offsite power.

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

Th is Surveillance shall not be performed in MODE 1, 2, or 3. (Not applicable to DG 1 C) However, credit may be taken for unplanned events that satisfy this SR.

Verify sequence time is within +/- 10% of design for each load sequencer timer.

FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program 3.8-14

( continued)

Amendment No. 81 121 133 168 487,196

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SR 3.8.1.19 RIVER BEND SURVEILLANCE

~-----NOTES----~-----~----------------

1.

All DG starts may be preceded by an engine prelube period.

2.

This Surveillance shall not be performed in MODE 1, 2, or 3. (Not applicable to DG 1 C)

However, credit may be taken for unplanned events that satisfy this SR Verify, on an actual or simulated loss of offsite power signal in conjunction with an actual or simulated ECCS initiation signal:

a.

De-energization of emergency buses;

b.

Load shedding from emergency buses for Divisions I and 11; and

c.

DG auto-starts from standby condition and:

1.

energizes permanently connected loads in

10 seconds for DG 1 A and DG 1 B and

13 seconds for DG 1 C,

2.

energizes auto-connected emergency

loads,

3.

achieves steady state voltage

i. for DG 1A and DG 1B 2 3740 Vand

~ 4368 V, ii. for DG 1C 2 3740 Vand:::; 4580 V,

4.

achieves steady state frequency 2 58.8 Hz and:::; 60.2 Hz, and

5.

supplies permanently connected and auto-connected emergency loads for

~ 5 minutes.

FREQUENCY In accordance with the Surveillance Frequency Control Program

( continued) 3.8-15 Amendment No. 81 121 165 487 196

SURVEILLANCE REQUIREMENTS (continued)

SR 3.8.1.20 SURVEILLANCE

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

AII DG starts may be preceded by an engine prelube period.

Verify, when started simultaneously from standby condition, each DG achieves:

1.

In~ 10 seconds for DG 1A and DG 18 and

~ 13 seconds for DG 1 C voltage 2 37 40 V and frequency 2 58.8 Hz, and

2.

Steady state voltage a) For DG 1A and DG 18 2 3740 Vand

~ 4368 V, b) For DG 1C 2 3740 Vand ~ 4580 V, and c) ForDG 1A, 18, and 1Cafrequency 2 58.8 Hz and ~ 60.2 Hz.

AC Sources-Operating 3.8.1 FREQUENCY In accordance with the Surveillance Frequency Control Program RIVER BEND 3.8-16 Amendment No. M, QG, 196

Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 SURVEILLANCE REQUIREMENTS SR 3.8.3.1 SR 3.8.3.2 SR 3.8.3.3 SR 3.8.3.4 SR 3.8.3.5 RIVER BEND SURVEILLANCE Verify each fuel oil storage tank contains ~ 45,495 gal of fuel.

Verify lube oil inventory is:

a.

~ 367 gal for DGs 1A and 1 B; and

b.

~ 295 gal for DG 1 C.

Verify fuel oil properties of new and stored fuel oil are tested in accordance with, and maintained within the limits of, the Diesel Fuel Oil Testing Program.

Verify each required DG air start receiver pressure is

a.

~ 160 psig for DGs 1A and 18; and

b.

~ 200 psig for DG 1 C.

Check for and remove accumulated water from each fuel oil storage tank.

FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Diesel Fuel Oil Testing Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program 3.8-23 Amendment No. 84-94, 4-eO, 196

DC Sources-Operating 3.8.4 SURVEILLANCE REQUIREMENTS SR 3.8.4.1 SR 3.8.4.2 SR 3.8.4.3 SR 3.8.4.4 SR 3.8.4.5 RIVER BEND SURVEILLANCE Verify battery terminal voltage is ~ 130.2 Von float charge.

Verify no visible corrosion at battery terminals and connectors.

OR Verify battery connection resistance is s 1.5 E-4 ohm for inter-cell connections, s 1.5 E-4 ohm for inter-rack connections, s 1.5 E-4 ohm for inter-tier connections, and s 1.5 E-4 ohm for terminal connections.

AND Verify the total resistance for battery inter-cell, inter-rack, inter-tier, and terminal connections combined is s 27.45 E-4 ohms.

Verify battery cells, cell plates, and racks show no visual indication of physical damage or abnormal deterioration.

Remove visible corrosion, and verify battery cell to cell and terminal connections are coated with anti-corrosion material.

Verify battery connection resistance is s 1.5 E-4 ohm for inter-cell connections, s 1.5 E-4 ohm for inter-rack connections, s 1.5 E-4 ohm for inter-tier connections, and s 1.5 E-4 ohm for terminal connections.

AND Verify the total resistance for battery inter-cell, inter-rack, inter-tier, and terminal connections combined is s 27.45 E-4 ohms.

FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program 3.8-25 (continued)

Amendment No. 84, ~. 43i, 196

SURVEILLANCE REQUIREMENTS (continued)

SR 3.8.4.6 SR 3.8.4.7 SURVEILLANCE Verify each battery charger supplies 2 300 amps for chargers 1 A and 1 B and 2 50 amps for charger 1 C at 2 130.2 V for 2 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months .

NOTES------------------------------

1.

SR 3.8.4.8 may be performed in lieu of SR 3.8.4. 7 once per 60 months.

2.

This Surveillance shall not be performed in MODE 1, 2, or 3 (not applicable to Division Ill).

However, credit may be taken for unplanned events that satisfy this SR.

Verify battery capacity is adequate to supply, and maintain in OPERABLE status, the required emergency loads for the design duty cycle when subjected to a battery service test.

DC Sources-Operating 3.8.4 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued)

RIVER BEND 3.8-26 Amendment No. 81 141, 498, 196

DC Sources-Operating 3.8.4 SURVEILLANCE REQUIREMENTS continued SR 3.8.4.8 RIVER BEND SURVEILLANCE

N()TE------------------------------

This Surveillance shall not be performed in MODE 1, 2, or 3 (not applicable to Division 111). However, credit may be taken for unplanned events that satisfy this SR.

Verify battery capacity is ~ 80% of the manufacturer's rating when subjected to a performance discharge test.

FREQUENCY In accordance with the Surveillance Frequency Control Program AND

NOTE-------

()nly applicable when battery shows degradation or has reached 85% of expected life.

18 months 3.8-27 Amendment No. 444-, 196

ACTIONS (continued)

CONDITION B.

Required Action and associated Completion Time of Condition A not met.

OR One or more batteries with average electrolyte temperature of the representative cells

< 60°F.

OR One or more batteries with one or more battery cell parameters not within Category C limits.

SURVEILLANCE REQUIREMENTS B.1 REQUIRED ACTION Declare associated battery inoperable.

SURVEILLANCE SR 3.8.6.1 RIVER BEND Verify battery cell parameters meet Table 3.8.6-1 Category A limits.

3.8-32 "Battery Cell Parameters 3.8.6 COMPLETION TIME Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program (continued)

Amendment No. 84, 196

SURVEILLANCE REQUIREMENTS (continued)

SR 3.8.6.2 SR 3.8.6.3 RIVER BEND SURVEILLANCE Verify battery cell parameters meet Table 3.8.6-1 Category B limits.

Verify average electrolyte temperature of representative cells is 2'.: 60°F.

3.8-33 Battery Cell Parameters 3.8.6 FREQUENCY In accordance with the Surveillance Frequency Control Program Once within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months after battery overcharge

> 144 V In accordance with the Surveillance Frequency Control Program Amendment No. 84, 196

3.8 ELECTRICAL POWER SYSTEMS 3.8. 7 Inverters-Operating Inverters-Operating 3.8.7 LCO 3.8.7 The Division I and Division II inverters shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3.

ACTIONS

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

Enter applicable Conditions and Required Actions of LCO 3.8.9, "Distribution Systems-Operating," with any AC vital bus de-energized.

CONDITION REQUIRED ACTION A.

Division I or II inverter A.1 Restore Division I and II inoperable.

inverters to OPERABLE status.

B.

Required Action and B.1

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

associated Completion LCO 3.0.4.a is not Time of Condition A not applicable when entering met.

MODE 3.

Be in MODE 3.

SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.8.7.1 RIVER BEND Verify correct inverter voltage, frequency, and alignment to required AC vital buses.

3.8-35 COMPLETION TIME 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months 12 hours FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment No. 84, ~. 196

ACTIONS CONDITION REQUIRED ACTION A. (continued)

A.2.3 Initiate action to restore required *inverters to OPERABLE status.

SURVEILLANCE REQUIREMENTS SR 3.8.8.1 RIVER BEND SURVEILLANCE Verify correct inverter voltage, frequency, and alignments to required AC vital buses.

3.8-37 Inverters-Shutdown 3.8.8 COMPLETION TIME Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment No. 84, 493, 196

Distribution Systems-Operating 3.8.9 SURVEILLANCE REQUIREMENTS SR 3.8.9.1 RIVER BEND SURVEILLANCE Verify correct breaker alignments and voltage to required AC, DC, and AC vital bus electrical power distribution subsystems.

3.8-40 FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment No. 34-, 196

Distribution Systems-Shutdown 3.8.10 ACTIONS (continued)

CONDITION A. (continued)

REQUIRED ACTION A.2.3 Initiate actions to restore required AC, DC, and AC vital bus electrical power distribution subsystems to OPERABLE status.

COMPLETION TIME Immediately A.2.4 Declare associated required Immediately shutdown cooling subsystem(s) inoperable and not in operation.

SURVEILLANCE REQUIREMENTS SR 3.8.10.1 SURVEILLANCE Verify correct breaker alignments and voltage to required AC, DC, and AC vital bus electrical power distribution subsystems.

FREQUENCY In accordance with the Surveillance Frequency Control Program RIVER BEND 3.8-42 Amendment No. 84-, 4-W, 196

Refueling Equipment Interlocks 3.9.1 SURVEILLANCE REQUIREMENTS SR 3.9.1.1 RIVER BEND SURVEILLANCE Perform CHANNEL FUNCTIONAL TEST on each of the following required refueling equipment interlock inputs:

a.

All-rods-in,

b.

Refuel platform position, and

c.

Refuel platform main hoist, fuel loaded.

FREQUENCY In accordance with the Surveillance Frequency Control Program 3.9-1a Amendment No. 8-1-, +04, 196

Refueling Position One-Rod-Out Interlock 3.9.2 3.9 REFUELING OPERATIONS 3.9.2 Refuel Position One-Rod-Out Interlock LCO 3.9.2 The refuel position one-rod-out interlock shall be OPERABLE.

APPLICABILITY:

MODE 5 with the reactor mode switch in the refuel position and any control rod withdrawn.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

Refuel position one-rod-out A.1 Suspend control rod Immediately interlock inoperable.

withdrawal.

A.2 Initiate action to fully insert all Immediately insertable control rods in core cells containing one or more fuel assemblies.

SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.9.2.1 Verify reactor mode switch locked in refuel position.

RIVER BEND 3.9-2 FREQUENCY In accordance with the Surveillance Frequency Control Program (continued)

Amendment No. 84, 196

Refueling Position One-Rod-Out Interlock 3.9.2 SURVEILLANCE REQUIREMENTS continued SR 3.9.2.2 RIVER BEND SURVEILLANCE FREQUENCY

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

Not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after any control rod is withdrawn.

Perform CHANNEL FUNCTIONAL TEST.

3.9-3 In accordance with the Surveillance Frequency Control Program Amendment No. 84, 196

3.9 REFUELING OPERATIONS 3.9.3 Control Rod Position LCO 3.9.3 All control rods shall be fully inserted.

APPLICABILITY:

When loading fuel assemblies into the core.

ACTIONS CONDITION A.

One or more control rods not fully inserted.

SURVEILLANCE REQUIREMENTS REQUIRED ACTION A.1 Suspend loading fuel assemblies into the core.

SURVEILLANCE SR 3.9.3.1 Verify all control rods are fully inserted.

RIVER BEND 3.9-4 Control Rod Position 3.9.3 COMPLETION TIME Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program Amendment No. ~. 196

Control Rod OPERABILITY - Refueling 3.9.5 3.9 REFUELING OPERATIONS 3.9.5 Control Rod OPERABILITY - Refueling LCO 3.9.5 Each withdrawn control rod shall be OPERABLE.

APPLICABILITY:

MODE 5.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

One or more withdrawn control rods inoperable.

A.1 Initiate action to fully insert Immediately inoperable withdrawn control rods.

SURVEILLANCE REQUIREMENTS SR 3.9.5.1 SR 3.9.5.2 RIVER BEND SURVEILLANCE

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

Not required to be performed until 7 days after the control rod is withdrawn.

FREQUENCY Insert each withdrawn control rod at least one notch.

In accordance with the Surveillance Frequency Control Program Verify each withdrawn control rod scram accumulator pressure is ~ 1540 psig.

In accordance with the Surveillance Frequency Control Program 3.9-7 Amendment No. 84, 444, 196

RPV Water Level -Irradiated Fuel 3.9.6 3.9 REFUELING OPERATIONS 3.9.6 Reactor Pressure Vessel (RPV) Water Level - Irradiated Fuel LCO 3.9.6 RPV water level shall be ~ 23 ft above the top of the RPV flange.

APPLICABILITY:

During movement of irradiated fuel assemblies within the RPV.

ACTIONS CONDITION REQUIRED ACTION A.

RPV water level not within A.1 Suspend movement of limit.

irradiated fuel assemblies within the RPV.

SURVEILLANCE REQUIREMENTS SR 3.9.6.1 SURVEILLANCE Verify RPV water level is ~ 23 ft above the top of the RPVflange.

COMPLETION TIME Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program RIVER BEND 3.9-8 Amendment No. 84, 196

RPV Water Level - New Fuel or Control Rods 3.9.7 3.9 REFUELING OPERATIONS 3.9.7 Reactor Pressure Vessel (RPV) Water Level - New Fuel or Control Rods LCO 3.9. 7 RPV water level shall be ~ 23 ft above the top of irradiated fuel assemblies seated within the RPV.

APPLICABILITY:

During movement of new fuel assemblies or handling of control rods within the RPV when irradiated fuel assemblies are seated within the RPV.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

RPV water level not within A.1 Suspend movement of new Immediately limit.

fuel assemblies and handling of control rods within the RPV.

SURVEILLANCE REQUIREMENTS SR 3.9.7.1 RIVER BEND SURVEILLANCE FREQUENCY Verify RPV water level is ~ 23 ft above the top of In accordance with irradiated fuel assemblies seated within the RPV.

the Surveillance Frequency Control Program 3.9-9 Amendment No. 84, 196

ACTIONS ( continued)

CONDITION REQUIRED ACTION B.

(continued) 8.3

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

Entry and exit is permissible under administrative control.

Initiate action to close one door in each primary containment air lock.

C.

No RHR shutdown cooling C. 1 Verify reactor coolant subsystem in operation.

circulation by an alternate method.

AND C.2 Monitor reactor coolant temperature.

SURVEILLANCE REQUIREMENTS SR 3.9.8.1 SR 3.9.8.2 SURVEILLANCE Verify one RHR shutdown cooling subsystem is operating.

Verify required RHR shutdown cooling subsystem locations susceptible to gas accumulation are sufficiently filled with water.

RHR - High Water Level 3.9.8 COMPLETION TIME Immediately 1 hourfrom discovery of no reactor coolant circulation AND Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter Once per hour FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program RIVER BEND 3.9-11 Amendment No. M,.:t,.gg, 196

ACTIONS (continued)

CONDITION REQUIRED ACTION B.

(continued) 8.2

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

Entry and exit is permissible under administrative control.

Initiate action to close one door in each primary containment air lock.

C.

No RHR shutdown cooling C.1 Verify reactor coolant subsystem in operation.

circulation by an alternate method.

AND C.2 Monitor reactor coolant temperature.

SURVEILLANCE REQUIREMENTS SR 3.9.9.1 SR 3.9.9.2 SURVEILLANCE Verify one RHR shutdown cooling subsystem is operating.

Verify required RHR shutdown cooling subsystem locations susceptible to gas accumulation are sufficiently filled with water.

RHR-Low Water Level 3.9.9 COMPLETION TIME Immediately 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from discovery of no reactor coolant circulation AND Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter Once per hour FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program RIVER BEND 3.9-13 Amendment No. 84-, 488, 196

Reactor Mode Switch Interlock Testing 3.10.2 ACTIONS ( continued)

CONDITION REQUIRED ACTION COMPLETION TIME A.

(continued)

A.3.1 OR Place the reactor mode 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months switch in the shutdown position.

A.3.2

NOTE----------

Only applicable in MODE 5.

Place the reactor mode 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months switch in the refuel position.

SURVEILLANCE REQUIREMENTS SR 3.10.2.1 SR 3.10.2.2 RIVER BEND SURVEILLANCE Verify all control rods are fully inserted in core cells containing one or more fuel assemblies.

Verify no CORE AL TERA TIONS are in progress.

3.10-5 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment No. 84-, 196

Single Control Rod Withdrawal - Hot Shutdown 3.10.3 SURVEILLANCE REQUIREMENTS SR 3.10.3.1 SR 3.10.3.2 SR 3.10.3.3 RIVER BEND SURVEILLANCE Perform the applicable SRs for the required LCOs.

FREQUENCY According to the applicable SRs

N()TE-----------------------------------

Not required to be met if SR 3.10.3.1 is satisfied for LC() 3.10.3.d.1 requirements.

Verify all control rods, other than the control rod being withdrawn, in a five by five array centered on the control rod being withdrawn, are disarmed.

Verify all control rods, other than the control rod being withdrawn, are fully inserted.

3.10-8 In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment No. 84, 196

Single Control Rod Withdrawal - Cold Shutdown 3.10.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B.

One or more of the above B.1 Suspend withdrawal of Immediately requirements not met with the affected control rod not insertable.

AND B.2.1 OR the control rod and removal of associated CRD.

Initiate action to fully insert all control rods.

Immediately B.2.2 Initiate action to satisfy Immediately the requirements of this LCO.

SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.10.4.1 Perform the applicable SRs for the required LCOs.

FREQUENCY According to applicable SRs SR 3.10.4.2

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

RIVER BEND Not required to be met if SR 3.10.4.1 is satisfied for LCO 3.10.4.c.1 requirements.

Verify all control rods, other than the control rod being withdrawn, in a five by five array centered on the control rod being withdrawn, are disarmed.

3.10-11 In accordance with the Surveillance Frequency Control Program (continued)

Amendment No. 84, 196

Single Control Rod Withdrawal - Cold Shutdown 3.10.4 SURVEILLANCE REQUIREMENTS (continued)

SR 3.10.4.3 SR 3.10.4.4 RIVER BEND SURVEILLANCE Verify all control rods, other than the control rod being withdrawn, are fully inserted.

N()TE-------------------------------

Not required to be met if SR 3.10.4.1 is satisfied for LCO 3.10.4.b.1 requirements.

Verify a control rod withdrawal block is inserted.

3.10-12 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment No. 84, 196

Single CRD Removal - Refueling 3.10.5 ACTIONS ( continued)

CONDITION REQUIRED ACTION COMPLETION TIME A.

(continued)

A.2.1 OR Initiate action to fully insert all control rods.

Immediately A.2.2 Initiate action to satisfy Immediately the requirements of this LCO.

SURVEILLANCE REQUIREMENTS SR 3.10.5.1 SR 3.10.5.2 SR 3.10.5.3 RIVER BEND SURVEILLANCE Verify all controls rods, other than the control rod withdrawn for the removal of the associated CRD, are fully inserted.

Verify all control rods, other than the control rod withdrawn for the removal of the associated CRD, in a five by five array centered on the control rod withdrawn for the removal of the associated CRD, are disarmed.

Verify a control rod withdrawal block is inserted.

FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued) 3.10-14 Amendment No. M, 196

Single CRD Removal - Refueling 3.10.5 SURVEILLANCE REQUIREMENTS (continued}

SR 3.10.5.4 SR 3.10.5.5 RIVER BEND SURVEILLANCE FREQUENCY Perform SR 3.1.1.1.

According to SR 3.1.1.1 Verify no CORE ALTERATIONS are in progress.

In accordance with the Surveillance Frequency Control Program 3.10-15 Amendment No. 84-, 196

Multiple Control Rod Withdrawal-Refueling 3.10.6 ACTIONS (continued)

CONDITION A.

(continued)

A.3.1 REQUIRED ACTION OR Initiate action to fully insert all control rods in core cells containing one or more fuel assemblies.

COMPLETION TIME Immediately A.3.2 Initiate action to satisfy Immediately the requirements of this LCO.

SURVEILLANCE REQUIREMENTS SR 3.10.6.1 SR 3.10.6.2 SR 3.10.6.3 RIVER BEND SURVEILLANCE Verify the four fuel assemblies are removed from core cells associated with each control rod or CRD removed.

Verify all other control rods in core cells containing one or more fuel assemblies are fully inserted.

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

Only required to be met during fuel loading.

Verify fuel assemblies being loaded are in compliance with an approved spiral reload sequence.

3.10-17 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment No. 84, 196

SOM Test-Refueling 3.10.8 SURVEILLANCE REQUIREMENTS (continued)

SR 3.10.8.2 SR 3.10.8.3 SR 3.10.8.4 RIVER BEND SURVEILLANCE FREQUENCY

N()TE----------------------------------

Not required to be met if SR 3.10.8.3 satisfied.

Perform the MODE 2 applicable SRs for LC() 3.3.2.1, According to the Function 1.b of Table 3.3.2.1-1.

applicable SRs

N()TE---------------------------------

Not required to be met if SR 3.10.8.2 satisfied.

Verify movement of control rods is in compliance with During control rod the approved control rod sequence for the SOM test movement by a second licensed operator or other qualified member of the technical staff.

Verify no other CORE AL TERA TIONS are in progress.

3.10-21 In accordance with the Surveillance Frequency Control Program (continued)

Amendment No. 84-, 196

SURVEILLANCE REQUIREMENTS (continued)

SR 3.10.8.5 SR 3.10.8.6 SURVEILLANCE Verify each withdrawn control rod does not go to the withdrawn overtravel position.

Verify CRD charging water header pressure 2 1540 psig.

SDM Test-Refueling 3.10.8 FREQUENCY Each time the control rod is withdrawn to "full out" position Prior to satisfying LCO 3.10.8.c requirement after work on control rod or CRD System that could affect coupling In accordance with the Surveillance Frequency Control Program RIVER BEND 3.10-22 Amendment No. 84, 444, 196

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.7 RIVER BEND ASME OM Code and applicable Addenda terminology for inservice testing activities Weekly Monthly Quarterly or every 3 months Semiannually or every 6 months Every 9 months Yearly or annually Biennially or every 2 years Required frequencies for performing inservice testing activities At least once per 7 days At least once per 31 days At least once per 92 days At least once per 184 days At least once per 276 days At least once per 366 days At least once per 731 days

b.

The provisions of SR 3.0.2 are applicable to the above required frequencies and to other normal and accelerated frequencies specified as 2 years or less in the lnservice Testing Program for performing inservice testing activities;

c.

The provisions of SR 3.0.3 are applicable to inservice testing activities; and

d.

Nothing in the ASME OM Code shall be construed to supersede the requirements of any TS.

Ventilation Filter Testing Program (VFTP)

A program shall be established to implement the following required testing of Engineered Safety Feature (ESF) filter ventilation systems at the frequencies specified in Regulatory Guide 1.52, Revision 2, except that testing specified at a frequency of 18 months is required at a frequency in accordance with the Surveillance Frequency Control Program.

(continued) 5.0-11 Amendment No. ~. 4-ea, 467, 468, 196

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.7 RIVER BEND Ventilation Filter Testing Program (VFTP) (continued)

a.

Demonstrate for each of the ESF systems that an inplace test of the high efficiency particulate air (HEPA) filters shows a penetration and system bypass < 0.05% when tested in accordance with Regulatory Guide 1.52, Revision 2, and ASME N510-1989 at the system flowrate specified below

+/- 10%:

ESF Ventilation System SGTS FBVS CRFAS Flowrate 12,500 cfm 10,000 cfm 4,000 cfm

b.

Demonstrate for each of the ESF systems that an inplace test of the charcoal adsorber shows a penetration and system bypass< 0.05% when tested in accordance with Regulatory Guide 1.52, Revision 2, and ASME N510-1989 at the system flowrate specified below+/- 10%:

ESF Ventilation System SGTS FBVS CRFAS Flowrate 12,500 cfm 10,000 cfm 4,000 cfm

c.

Demonstrate for each of the ESF systems that a laboratory test of a sample of the charcoal adsorber, when obtained as described in Regulatory Guide 1.52, Revision 2, shows the methyl iodide penetration less than the value specified below when tested in accordance with ASTM D3803-1989 at a temperature of 30°C and the relative humidity specified below:

ESF Ventilation System SGTS FBVS CRFAS 5.0-12 Penetration 5.0%

5.0%

1.0%

RH 95%

95%

(continued)

Amendment No. 84-, 44-a, ~. 4ee, ~

196

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.7 Ventilation Filter Testing Program (VFTP) (continued) 5.5.8 5.5.9 RIVER BEND

d.

Demonstrate for each of the ESF systems that the pressure drop across the combined HEPA filters, the prefilters, and the charcoal adsorbers is less than the value specified below when tested in accordance with Regulatory Guide 1.52, Revision 2, and ASME N510-1989 at the system flowrate specified below+/- 10%:

ESF Ventilation System SGTS FBVS CRFAS Delta P

<8"WG

<8"WG Flowrate 12,500 cfm 10,000 cfm 4,000 cfm The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the VFTP test frequencies.

Explosive Gas and Storage Tank Radioactivity Monitoring Program This program provides controls for potentially explosive gas mixtures contained in the main condenser offgas treatment system and the quantity of radioactivity contained in unprotected outdoor liquid storage tanks.

The program shall include:

a.

The limits for concentrations of hydrogen in the main condenser offgas treatment system and a surveillance program to ensure the limits are maintained. Such limits shall be appropriate to the system's design criteria (i.e., whether or not the system is designed to withstand a hydrogen explosion); and

b.

A surveillance program to ensure that the quantity of radioactive material contained in any unprotected outdoor tank is limited to ~ 10 curies, excluding tritium and dissolved or entrained noble gases.

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Explosive Gas and Storage Tank Radioactivity Monitoring Program surveillance frequencies.

Diesel Fuel Oil Testing Program A diesel fuel oil testing program to implement required testing of both new fuel oil and stored fuel oil shall be established. The (continued) 5.0-13 Amendment No. 84, 4W, ~. 196

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.9 5.5.10 RIVER BEND Diesel Fuel Oil Testing Program (continued) program shall include sampling and testing requirements, and acceptance criteria, all in accordance with applicable ASTM Standards. The purpose of the program is to establish the following:

a.

Acceptability of new fuel oil for use prior to addition to storage tanks by determining that the fuel oil has:

1.

an API gravity or an absolute specific gravity within limits,

2.

a flash point and kinematic viscosity within limits for ASTM 2D fuel oil, and

3.

a clear and bright appearance with proper color;

b.

Other properties of the new fuel oil are within limits for ASTM 2D fuel oil within 31 days of addition to storage tanks; and

c.

Total particulate concentration of the fuel oil in the storage tanks is

< 10 mg/I when tested in accordance with ASTM D-2276, Method A-2 or A-3 at a frequency in accordance with the Surveillance Frequency Control Program.

Safety Function Determination Program (SFDP)

This program ensures loss of safety function is detected and appropriate actions taken. Upon entry into LCO 3.0.6, an evaluation shall be made to determine if loss of safety function exists. Additionally, other appropriate limitations and remedial or compensatory actions may be identified to be taken as a result of the support system inoperability and corresponding exception to entering supported system Condition and Required Actions. This program implements the requirements of LCO 3.0.6. The SFDP shall contain the following:

a.

Provisions for cross division checks to ensure a loss of the capability to perform the safety function assumed in the accident analysis does not go undetected;

b.

Provisions for ensuring the plant is maintained in a safe condition if a loss of function condition exists; (continued) 5.0-14 Amendment No. 84, 196

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.11 5.5.12 5.5.13 RIVER BEND Technical Specifications (TS) Bases Control Program (continued)

c.

The Bases Control Program shall contain provisions to ensure that the Bases are maintained consistent with the USAR.

d.

Proposed changes that do not meet the criteria of either Specification 5.5.11.b.1 or Specification 5.5.11.b.2 above shall be reviewed and approved by the NRC prior to implementation. Changes to the Bases implemented without prior NRC approval shall be provided to the NRC on a frequency consistent with 10 CFR 50.71(e).

Surveillance Frequency Control Program This program provides controls for Surveillance Frequencies. The program shall ensure that Surveillance Requirements specified in the Technical Specifications are performed at intervals sufficient to assure the associated Limiting Conditions for Operation are met.

a.

The Surveillance Frequency Control Program shall contain a list of Frequencies of those Surveillance Requirements for which the Frequency is controlled by the program.

b.

Changes to the Frequencies listed in the Surveillance Frequency Control Program shall be made in accordance with NEI 04-10, "Risk-Informed Method for Control of Surveillance Frequencies," Revision 1.

c.

The provisions of Surveillance Requirements 3.0.2 and 3.0.3 are applicable to the Frequencies established in the Surveillance Frequency Control Program.

Primary Containment Leakage Rate Testing Program A program shall be established to implement the leakage rate testing of the containment as required by 10 CFR 50.54(0) and 10 CFR 50, Appendix J, Option B, as modified by approved exemptions. This program shall be in accordance with the guidelines contained in NEI 94-01, "Industry Guideline for Implementing Performance-Based Option of 10 CFR 50, Appendix J," Revision 3-A, dated July 2012, and the conditions and limitations specified in NEI 94-01, Revision 2-A, Section 4.1, dated October 2008.

The peak calculated containment internal pressure for the design basis loss of coolant accident, Pa, is 7.6 psig.

5.0-16 (continued)

Amendment No. 81 84 05 131 132 150 §4 ae, 9-1-, 196

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.13 5.5.14 RIVER BEND Primary Containment Leakage Rate Testing Program (continued)

The maximum allowable primary containment leakage rate, La, at Pa, shall be 0.325% of primary containment air weight per day.

The Primary Containment leakage rate acceptance criterion is:::; 1.0 La. During the first unit startup following testing in accordance with this program, the leakage rate acceptance criteria are:::; 0.60 La for the Type Band Type C tests and :::; 0. 75 La for Type A tests.

The provisions of SR 3.0.2 do not apply to test frequencies specified in the Primary Containment Leakage Rate Testing Program.

The provisions of SR 3.0.3 are applicable to the Primary Containment Leakage Rate Testing Program.

Control Room Envelope Habitability Program A Control Room Envelope (CRE) Habitability Program shall be established and implemented to ensure that CRE habitability is maintained such that, with an OPERABLE Control Room Fresh Air (CRFA) System, CRE occupants can control the reactor safely under normal conditions and maintain it in a safe condition following a radiological event, hazardous chemical release, or a smoke challenge. The program shall ensure that adequate radiation protection is provided to permit access and occupancy of the CRE under design basis accident (OBA) conditions without personnel receiving radiation exposures in excess of 5 rem total effective dose equivalent (TEDE) for the duration of the accident. The program shall include the following elements:

a.

The definition of the CRE and the CRE boundary.

b.

Requirements for maintaining the CRE boundary in its design condition including configuration control and preventive maintenance.

c.

Requirements for (i) determining the unfiltered air inleakage past the CRE boundary into the CRE in accordance with the testing methods and at the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, "Demonstrating Control Room Envelope Integrity at Nuclear Power Reactors," Revision 0, May 2003, and, (ii) assessing CRE habitability at the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, Revision 0, except that testing specified at a frequency of 18 months is required at a frequency in accordance with the Surveillance Frequency Control Program.

(continued) 5.0-16a Amendment No. 4a4, 4-88, 196

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.14 RIVER BEND Control Room Envelope Habitability Program (continued)

d.

Measurement, at designated locations, of the CRE pressure relative to all external areas adjacent to the CRE boundary during the pressurization mode of operation by one subsystem of the CRFA System, operating at the flow rate required by the VFTP, at a Frequency in accordance with the Surveillance Frequency Control Program. The results shall be trended and used as part of the CRE boundary assessment specified in 5.5.14.c (ii).

e.

The quantitative limits on unfiltered air inleakage into the CRE. These limits shall be stated in a manner to allow direct comparison to the unfiltered air inleakage measured by the testing described in paragraph c.

The unfiltered air inleakage limit for radiological challenges is the inleakage flow rate assumed in the licensing basis analyses of DBA consequences. Unfiltered air inleakage limits for hazardous chemicals must ensure that exposure of CRE occupants to these hazards will be within the assumptions in the licensing basis.

f.

The provisions of SR 3.0.2 are applicable to the Frequencies for assessing CRE habitability, determining CRE unfiltered inleakage, and measuring CRE pressure and assessing the CRE boundary as required by paragraphs c and d, respectively.

5.0-16b Amendment No. 196

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 SAFETY EVALUATION BY THE OFFICE OF NUCLEAR REACTOR REGULATION RELATED TO AMENDMENT NO. 196 TO RENEWED FACILITY OPERATING LICENSE NO. NPF-47 ENTERGY OPERATIONS. INC.

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

1.0 INTRODUCTION

By application dated February 28, 2018 (Reference 1 ), as supplemented by letters dated July 10, July 24, December 17, and December 20, 2018 (References 2, 3, 4, and 5, respectively), Entergy Operations, Inc. (Entergy, the licensee) submitted a request for changes to the technical specifications (TSs) for River Bend Station, Unit 1 (RBS).

The proposed changes would modify the TSs to adopt the U.S. Nuclear Regulatory Commission (NRC)-approved Technical Specifications Task Force (TSTF) Standard Technical Specifications (STSs) Change Traveler TSTF-425, Revision 3, "Relocate Surveillance Frequencies to Licensee Control - RITSTF [Risk-Informed TSTF] Initiative 5b" (Reference 6) for RBS.

The supplemental letters dated July 10, July 24, December 17, and December 20, 2018, provided additional information that clarified the application, did not expand the scope of the application as originally noticed, and did not change the NRC staff's original proposed no significant hazards consideration determination as published in the Federal Register (FR) on May 22, 2018 (83 FR 23733).

2.0

2.1 REGULATORY EVALUATION

Description of the Proposed Changes The licensee proposed to modify the TSs by relocating specific surveillance requirement (SR) frequencies to a licensee-controlled program in accordance with Nuclear Energy Institute (NEI) 04-10, Revision 1 (Reference 7). The licensee stated that the proposed change is consistent with the adoption of NRG-approved TSTF-425, Revision 3. When implemented, TSTF-425 allows licensees to relocate most periodic frequencies of TS SRs to a licensee-controlled program, referred to as the Surveillance Frequency Control Program (SFCP), and provides requirements for the new program in the Administrative Controls section of the TSs. All surveillance frequencies can be relocated except the following:

Frequencies that reference other approved programs for the specific interval such as the lnservice Testing Program or the Primary Containment Leakage Rate Testing Program; Frequencies that are purely event-driven (e.g., "each time the control rod is withdrawn to the 'full out' position");

Frequencies that are event-driven, but have a time component for performing the surveillance on a one-time basis once the event occurs (e.g., "within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after thermal power reaching ~ [greater than or equal to] 95% RTP [rated thermal power]"); and Frequencies that are related to specific conditions (e.g., battery degradation, age and capacity) or conditions for the performance of a surveillance requirement (e.g.,

"drywall to suppression chamber differential pressure decrease").

The licensee proposed to relocate specific surveillance frequencies from the following TS sections to the SFCP:

3.1 Reactivity Control System 3.2 Power Distribution Limits 3.3 Instrumentation 3.4 Reactor Coolant System (RCS) 3.5 Emergency Core Cooling Systems (ECCS), Reactor Pressure Vessel (RPV)

Water Inventory Control, and Reactor Core Isolation Cooling (RCIC) System 3.6 Containment Systems

3. 7 Plant Systems 3.8 Electrical Power Systems 3.9 Refueling Operations

3. 1 O Special Operations The licensee proposed to add the SFCP to RBS TS Chapter 5.0, "Administrative Controls."

Proposed TS 5.5.12, "Surveillance Frequency Control Program," describes the requirements for the SFCP to control changes to the relocated surveillance frequencies to ensure that surveillances are performed at intervals to ensure limiting conditions for operation (LCOs) are met. The TS Bases for each affected surveillance would be revised to state that the surveillance frequency is controlled under the SFCP, and were included in the application for information only. The proposed changes to the Administrative Controls section of the TSs include a specific reference to NEI 04-10, Revision 1, as the basis for making any changes to the surveillance frequencies when they are relocated out of the TSs.

In a letter dated September 19, 2007 (Reference 8), the NRC staff approved Topical Report NEI 04-10, Revision 1, as an acceptable methodology for referencing in licensing actions to the extent specified in NEI 04-10, Revision 1, and under the limitations and conditions delineated in the safety evaluation (SE) providing the basis for NRC acceptance of NEI 04-10, Revision 1.

The licensee proposed other changes and deviations from TSTF-425, which are discussed in SE Section 3.3, "Deviations from TSTF-425 and Other Changes."

2.2 Applicable Commission Policy Statements In the "Final Policy Statement: Technical Specifications Improvements for Nuclear Power Reactors," dated July 22, 1993 (58 FR 39132), the NRC addressed the use of probabilistic safety analysis (PSA, currently referred to as probabilistic risk assessment or PRA) in STS. In this 1993 publication, the NRC states (at 39135):

The Commission believes that it would be inappropriate at this time to allow requirements which meet one or more of the first three criteria [of Title 10 of the Code of Federal Regulations (10 CFR), Section 50.36(a)(2)(ii)] to be deleted from Technical Specifications based solely on PSA (Criterion 4). However, if the results of PSA indicate that Technical Specifications can be relaxed or removed, a deterministic review will be performed....

The Commission Policy in this regard is consistent with its Policy Statement on "Safety Goals for the Operation of Nuclear Power Plants," 51 FR 30028, published on August 21, 1986. The Policy Statement on Safety Goals states in part, "* *

probabilistic results should also be reasonably balanced and supported through use of deterministic arguments. In this way, judgments can be made * *

about the degree of confidence to be given these [probabilistic]

estimates and assumptions. This is a key part of the process of determining the degree of regulatory conservatism that may be warranted for particular decisions.

This defense-in-depth approach is expected to continue to ensure the protection of public health and safety."...

The Commission will continue to use PSA, consistent with its policy on Safety Goals, as a tool in evaluating specific line-item improvements to Technical Specifications, new requirements, and industry proposals for risk-based Technical Specification changes.

Approximately 2 years later, the NRC provided additional detail *concerning the use of PRA in the "Final Policy Statement: Use of Probabilistic Risk Assessment Methods in Nuclear Regulatory Activities," dated August 16, 1995 (60 FR 42622). In this publication, the NRC states, in part:

The Commission believes that an overall policy on the use of PRA methods in nuclear regulatory activities should be established so that the many potential applications of PRA can be implemented in a consistent and predictable manner that would promote regulatory stability and efficiency. In addition, the Commission believes that the use of PRA technology in NRC regulatory activities should be increased to the extent supported by the state-of-the-art in PRA methods and data and in a manner that complements the NRC's deterministic approach...

PRA addresses a broad spectrum of initiating events by assessing the event frequency. Mitigating system reliability is then assessed, including the potential for multiple and common cause failures. The treatment therefore goes beyond the single failure requirements in the deterministic approach. The probabilistic approach to regulation is, therefore, considered an extension and enhancement of traditional regulation by considering risk in a more coherent and complete manner....

Therefore, the Commission believes that an overall policy on the use of PRA in nuclear regulatory activities should be established so that the many potential applications of PRA can be implemented in a consistent and predictable manner that promotes regulatory stability and efficiency. This policy statement sets forth the Commission's intention to encourage the use of PRA and to expand the scope of PRA applications in all nuclear regulatory matters to the extent supported by the state-of-the-art in terms of methods and data....

Therefore, the Commission adopts the following policy statement regarding the expanded NRC use of PRA:

(1) The use of PRA technology should be increased in all regulatory matters to the extent supported by the state-of-the-art in PRA methods and data and in a manner that complements the NRC's deterministic approach and supports the NRC's traditional defense-in-depth philosophy.

(2) PRA and associated analyses (e.g., sensitivity studies, uncertainty analyses, and importance measures) should be used in regulatory matters, where practical within the bounds of the state-of-the-art, to reduce unnecessary conservatism associated with current regulatory requirements, regulatory guides, license commitments, and staff practices. Where appropriate, PRA should be used to support the proposal for additional regulatory requirements in accordance with 1 O CFR 50.109 (Backfit Rule). Appropriate procedures for including PRA in the process for changing regulatory requirements should be developed and followed. It is, of course, understood that the intent of this policy is that existing rules and regulations shall be complied with unless these rules and regulations are revised.

(3) PRA evaluations in support of regulatory decisions should be as realistic as practicable and appropriate supporting data should be publicly available for review.

(4) The Commission's safety goals for nuclear power plants and subsidiary numerical objectives are to be used with appropriate consideration of uncertainties in making regulatory judgments on the need for proposing and backfitting new generic requirements on nuclear power plant licensees.

2.3 Applicable Regulations In 1 O CFR 50.36, "Technical specifications," the NRC established its regulatory requirements related to the content of TSs. Pursuant to 10 CFR 50.36, TSs are required to include items in the following categories related to station operation: (1) safety limits, limiting safety system settings, and limiting control settings; (2) LCOs; (3) SRs; (4) design features; and (5) administrative controls. These categories will remain in the RBS TSs.

Paragraph 50.36(c)(3) of 10 CFR states, "[s]urveillance requirements 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 FR notice published on July 6, 2009 (74 FR 31996),

which announced the availability of TSTF-425, Revision 3, states that the addition of the SFCP to the TSs provides the necessary administrative controls to require that SR frequencies relocated to the SFCP are conducted at a frequency 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. The FR notice also states that changes to SR frequencies in the SFCP would be made using the methodology contained in NEI 04-10, Revision 1, including qualitative considerations, results of risk analyses, sensitivity studies and any bounding analyses, and recommended monitoring of structures, systems, and components (SSCs), and are required to be documented.

Existing regulatory requirements, such as 10 CFR 50.65, "Requirements for monitoring the effectiveness of maintenance at nuclear power plants" (i.e., the Maintenance Rule), and 10 CFR Part 50, Appendix B, Criterion XVI, "Corrective Action," require licensee monitoring of surveillance test failures and implementing corrective actions to address such failures. Such failures can result in the licensee increasing the frequency of a surveillance test. In addition, if the TSs are amended to require that changes to the frequencies listed in the SFCP be made in accordance with NEI 04-10, Revision 1, the licensee would be required to monitor the performance of SSCs for which SR frequencies are decreased to assure reduced testing does not adversely impact the SSCs.

2.4 Applicable NRC Regulatory Guides and Review Plans Regulatory Guide (RG) 1.17 4, Revision 3, "An Approach for Using Probabilistic Risk Assessment in Risk-Informed Decisions on Plant-Specific Changes to the Licensing Basis" (Reference 9), describes an acceptable risk-informed approach for assessing the nature and impact of proposed permanent licensing basis changes by considering engineering issues and applying risk insights. This RG also provides risk acceptance guidelines for evaluating the results of such evaluations.

RG 1.177, Revision 1, "An Approach for Plant-Specific, Risk-Informed Decisionmaking:

Technical Specifications" (Reference 10), describes an acceptable risk-informed approach specifically for assessing proposed TS changes.

RG 1.200, Revision 2, "An Approach for Determining the Technical Adequacy of Probabilistic Risk Assessment Results for Risk-Informed Activities" (Reference 11 ), describes an acceptable approach for determining whether the quality of the PRA, in total or the parts that are used to support an application, is sufficient to provide confidence in the results, such that the PRA can be used in regulatory decisionmaking for light-water reactors (LWRs).

NUREG-0800, "Standard Review Plan [SRP] for the Review of Safety Analysis Reports for Nuclear Power Plants: LWR Edition," Chapter 19, Section 19.2, "Review of Risk Information Used to Support Permanent Plant-Specific Changes to the Licensing Basis: General Guidance" (Reference 12), provides general guidance for evaluating the technical basis for proposed risk-informed changes. Guidance on evaluating PRA technical adequacy is provided in SRP, Chapter 19, Section 19.1, Revision 3, "Determining the Technical Adequacy of Probabilistic Risk Assessment for Risk-Informed License Amendment Requests After Initial Fuel Load" (Reference 13). More specific guidance related to risk-informed TS changes is provided in SRP, Chapter 16, Section 16.1, Revision 1, "Risk-Informed Decision Making: Technical Specifications" (Reference 14), which includes changes to surveillance test intervals (STls) (i.e.,

surveillance frequencies) as part of risk-informed decisionmaking. Section 19.2 of the SRP references the same criteria as RG 1.17 4, Revision 3, and RG 1.177, Revision 1, and states that a risk-informed application should be evaluated to ensure that the proposed changes meet the following key principles:

The proposed change meets the current regulations unless it is explicitly related to a requested exemption or rule change; The proposed change is consistent with the defense-in-depth philosophy; The proposed change maintains sufficient safety margins; When proposed changes result in an increase in core damage frequency (CDF) or risk, the increases should be small and consistent with the intent of the Commission's Safety Goal Policy Statement; The impact of the proposed change should be monitored using performance measurement strategies.

NUREG-1434, Revision 4, "Standard Technical Specifications, General Electric BWR [Boiling Water Reactor]/6 Plants," Volume 1, Specifications, and Volume 2, Bases (Reference 15),

contain the improved STS for General Electric BWR/6 plants. The improved STS were developed based on the criteria in the Final Commission Policy Statement of Technical Specifications Improvements for Nuclear Power Reactors, dated July 22, 1993 (58 FR 39132),

which was subsequently codified by changes to 10 CFR 50.36 (60 FR 36953). 1

3.0 TECHNICAL EVALUATION

The licensee's adoption of TSTF-425, Revision 3, would provide for relocation of applicable SR frequencies to the SFCP, would provide for the addition of the SFCP to the Administrative Controls section of TSs, and would require the application of NEI 04-10, Revision 1, for any changes to SR frequencies within the SFCP. The licensee's application for the changes proposed in TSTF-425, Revision 3, included documentation regarding technical adequacy of the PRA consistent with the requirements of RG 1.200, Revision 2. In accordance with NEI 04-10, Revision 1, PRA methods are used, in combination with plant performance data and other considerations, to identify and justify modifications to the surveillance frequencies of equipment at nuclear power plants. This is consistent with guidance provided in RG 1.17 4, Revision 3, and RG 1.177, Revision 1, in support of changes to STls.

3.1 Five Key Safety Principles The guidance in RG 1.177, Revision 1, outlines five key safety principles necessary for risk-informed changes to TSs. Each of these principles is addressed in NEI 04-10, Revision 1.

Section 3.1.1 through Section 3.1.5 of this SE discuss the five principles, including the NRC staffs evaluation of how the licensee's LAR satisfies each principle.

1 RBS converted to the standard TSs via amendment dated July 20, 1995 (ADAMS Accession No. ML021610732).

3.1.1 The Proposed Change Meets Current Regulations Paragraph 50.36(c)(3) of 10 CFR states that TSs will include surveillances which are "requirements relating to test, calibration, or inspection to assure that 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 licensee is required by its TSs to perform surveillance tests, calibration, or inspection on specific safety-related equipment (e.g.,

reactivity control, power distribution, electrical, and instrumentation) to verify system operability.

Surveillance frequencies are based primarily upon deterministic methods, such as engineering judgment, operating experience, and manufacturer's recommendations. The licensee's use of NRG-approved methodologies identified in NEI 04-10, Revision 1, provides a way to establish risk-informed surveillance frequencies that complements the deterministic approach and supports the NRC's traditional defense-in-depth philosophy.

The surveillances themselves would remain in the TSs as required by 10 CFR 50.36(c)(3), but the frequencies would be specified by references to the SFCP, which per proposed TS 5.5.12, must ensure that LCOs are met. This change is analogous to other NRG-approved TS changes in which the SRs are retained in the TSs, but the related surveillance frequencies are relocated to licensee-controlled documents, such as surveillances performed in accordance with the lnservice Testing Program (required by RBS TS 5.5.6) and the Primary Containment Leakage Rate Testing Program (required by RBS TS 5.5.13). Thus, this proposed change complies with 10 CFR 50.36(c)(3) by retaining the 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.

The requirements in 10 CFR 50.65 and 1 O CFR Part 50, Appendix B, Criterion XVI, and the monitoring of surveillance test failures that would be required by NEI 04-10, Revision 1, per proposed TS 5.5.12, will ensure that surveillance frequencies are sufficient to satisfy 10 CFR 50.36(c)(3) requirements and that any test failures will be identified and corrective actions will be implemented to address such failures. The licensee's SFCP ensures that SRs specified in the TSs are performed at intervals sufficient to assure that the above regulatory requirements are met. Based on the above, the NRC staff concludes that the proposed change to relocate surveillance frequencies meets the first key safety principle of RG 1.177, Revision 1, by complying with the current regulations.

3.1.2 The Proposed Change Is Consistent With the Defense-in-Depth Philosophy The defense-in-depth philosophy (i.e., the second key safety principle of RG 1.177, Revision 1 ),

is maintained if:

A reasonable balance is preserved among prevention of core damage, prevention of containment failure, and consequence mitigation.

Over-reliance on programmatic activities to compensate for weaknesses in plant design is avoided.

System redundancy, independence, and diversity are preserved commensurate with the expected frequency, consequences of challenges to the system, and uncertainties (e.g., no risk outliers). Because the scope of the proposed methodology is limited to revision of surveillance frequencies, the redundancy, independence, and diversity of plant systems are not impacted.

Defenses against potential common cause failures are preserved, and the potential for the introduction of new common cause failure mechanisms is assessed.

Independence of barriers is not degraded.

Defenses against human errors are preserved.

The intent of the General Design Criteria in 10 CFR Part 50, Appendix A, is maintained.

The adoption of TSTF-425, Revision 3, includes the application of NEI 04-10, Revision 1, for any changes to surveillance frequencies within the SFCP. The guidance in NEI 04-10, Revision 1, uses both the CDF and the large early release frequency (LERF) metrics to evaluate the impact of proposed changes to surveillance frequencies. The guidance in RG 1.17 4, Revision 3, and RG 1.177, Revision 1, for changes to CDF and LERF, is achieved by evaluation using a comprehensive risk analysis, which assesses the impact of proposed changes, including contributions from human errors and common cause failures. Defense-in-depth is also included in the methodology explicitly as a qualitative consideration outside of the risk analysis, as is the potential impact on detection of component degradation that could lead to an increased likelihood of common cause failures. The NRC staff concludes that both the quantitative risk analysis and the qualitative considerations assure that a reasonable balance of defense-in-depth is maintained in order to ensure protection of public health and safety, satisfying the second key safety principle of RG 1.177, Revision 1.

3.1.3 The Proposed Change Maintains Sufficient Safety Margins To evaluate a change in the relocated surveillance frequency, the licensee will perform a probabilistic risk evaluation using the guidance contained in NRG-approved NEI 04-10, Revision 1, in accordance with the SFCP. The licensee states that the SFCP provides the necessary administrative controls to require that SRs related to testing, calibration and inspection are conducted at a frequency 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. The engineering evaluation that will be conducted by the licensee under the SFCP when frequencies are revised will assess the impact of the proposed frequency change to assure that sufficient safety margins are maintained. The guidelines used to make that assessment will include ensuring the proposed surveillance test frequency change is not in conflict with approved industry codes and standards nor does it adversely affect any assumptions or inputs to the safety analysis, or, if such inputs are affected, justification is provided to ensure sufficient safety margin will continue to exist.

The design, operation, testing methods, and acceptance criteria for SSCs specified in applicable codes and standards (or alternatives approved for use by the NRC) will continue to be met as described in the plant licensing basis (including the Updated Final Safety Analysis Report and the Bases to TSs), because these are not affected by changes to the surveillance frequencies.

Similarly, there is no impact to safety analysis acceptance criteria as described in the plant licensing basis. As a result, the NRC staff concludes that safety margins are maintained by the proposed methodology, and, therefore, the third key safety principle of RG 1.177 is satisfied.

3.1.4 When Proposed Changes Result in an increase in Core Damage Frequency or Risk, the Increases Should be Small and Consistent with the Intent of the Commission's Safety Goal Policy Statement The guidance in RG 1.177, Revision 1, provides a framework for evaluating the risk impact of future changes to the surveillance frequencies in the SFCP. The risk evaluation includes the identification of the risk contribution from impacted surveillances, determination of the risk impact from the change to the proposed surveillance frequency, and performance of sensitivity and uncertainty evaluations. The adoption of TSTF-425, Revision 3 (which is reflected in proposed TS 5.5.12), includes the application of NEI 04-10, Revision 1, to any changes to the frequencies listed in the SFCP. The guidance in NEI 04-10, Revision 1, satisfies the intent of RG 1.177, Revision 1, guidelines for evaluating the change in risk, and for assuring that such changes are small by providing the technical methodology to support risk-informed TS for control of surveillance frequencies.

3.1.4.1 PRA Technical Adequacy The technical adequacy of the licensee's PRA must be commensurate with the safety significance of the proposed TS change and the role the PRA plays in justifying the change.

That is, the higher the change in risk or the greater the uncertainty in that risk from the requested TS change, or both, the more rigor that must go into ensuring the quality of the PRA.

Consistent with the information provided in Regulatory Issue Summary (RIS) 2007-06, "Regulatory Guide 1.200 Implementation," dated March 22, 2007 (Reference 16), the NRC staff used RG 1.200, Revision 2, to assess the technical adequacy of the PRA used to support risk-informed applications received after March 2010.

The guidance in RG 1.200, Revision 2, provides for assessing the technical acceptability of a PRA. RG 1.200 endorses (with clarifications and qualifications) the use of the following:

1. American Society of Mechanical Engineers (ASME)/American Nuclear Society (ANS)

RA-Sa-2009, "Addenda to ASME RA-S-2008 Standard for Level 1/Large Early Release Frequency Probabilistic Risk Assessment for Nuclear Power Plant Applications" (i.e., the PRA Standard) (Reference 17);

2. NEI 00-02, "Probabilistic Risk Assessment (PRA) Peer Review Process Guidance" (Reference 18); and

3. NEI 05-04, "Process for Performing Internal Events PRA Peer Reviews Using the ASME/ANS PRA Standard," Revision 2 (Reference 19).

RG 1.200, Revision 1 endorsed the internal events PRA standard ASME RA-Sb-2005, "Addenda to ASME RA-S-2002 Standard for Probabilistic Risk Assessment for Nuclear Power Plant Applications."

The RBS PRA to support the SFCP used an internal events PRA model, which included internal flooding. Additionally, the licensee performed an assessment of the PRA models used to support the SFCP using the guidance of RG 1.200, Revision 2, to assure that the PRA models were technically acceptable for use in assessing the change in risk due to changes to surveillance frequencies of SSCs, using plant-specific data and models. The guidance in NEI 04-10, Revision 1, necessitates that the supporting requirements of the PRA standard meet Capability Category II for the internal events PRA and any identified deficiencies to those supporting requirements be assessed further to determine any impacts of proposed decreases to surveillance frequencies, including the use of sensitivity studies where appropriate.

The licensee stated that the RBS internal events PRA model, Revision 5, underwent a full-scope peer review in April 2011. The Boiling Water Reactor Owners Group conducted the peer review and reviewed the PRA model against the ASME/ANS RA-Sa-2009 PRA standard as endorsed by RG 1.200, Revision 2. The licensee stated that it subsequently completed the RBS PRA model, Revision 6, which incorporated the resolutions to all of the significant Facts and Observations (F&Os) from the full-scope peer review, as well as a PRA upgrade incorporating updates to the internal flooding and LERF analyses. The licensee also stated that a focused-scope peer review of the PRA model (i.e., Revision 6 upgrade), for internal flooding and LERF, was conducted in September 2017 against the ASME/ANS RA-Sa-2009 PRA standard as endorsed by RG 1.200, Revision 2.

In Tables 1 and 2 of Attachment 2 to the LAR dated February 28, 2018 (Reference 1), the licensee provided a description and disposition of the F&Os from the 2011 and 2017 peer reviews, respectively. The NRC staff reviewed the summary of the peer review findings and the licensee's resolution or assessment of the impact of the use of the PRA to manage the SFCP.

The NRC staff determined whether any gaps in the PRA model were identified that could impact the use of the PRA and ensured that any identified gaps in meeting Capability Category II would be addressed in the SFCP by using the methodology in NEI 04-10, Revision 1, consistent with RG 1.200, Revision 2. For the F&Os described below, the licensee did not initially provide justification for concluding that the F&O had a minimal impact on the use of the PRA with respect to the changes to the surveillance frequencies in the SFCP or describe how the impact of the unresolved F&O would be evaluated. In response to NRC staff questions, the licensee provided additional information to address the F&Os.

By supplemental letter dated December 17, 2018 (Reference 4), the licensee provided updated resolutions and assessments. The 2017 focused-scope peer review team created F&O RB-6096, related to internal flooding Supporting Requirement IFSO-A4, which identified that no evaluation was performed to identify human-induced flooding mechanisms. In its letter dated December 17, 2018, the licensee stated that it reviewed the test and maintenance procedures for human-induced flooding mechanisms and identified that only vent and fill operations create an opening in a system. These openings are small and have a low associated flow rate. Therefore, the likelihood of a maintenance-induced flooding event of any significance is not significant. Based on the licensee's assessment of low likelihood of human induced flooding mechanisms, the NRC staff concludes that this F&O has a negligible impact on this use of the PRA for changes to the surveillance frequencies in the SFCP.

The 2017 focused-scope peer review team created F&O RB-6101, related to Supporting Requirement LE-F3, which identified that a review of key assumptions in the LERF analysis had not been performed. In its December 17, 2018 letter, the licensee clarified that the LERF analysis reviews the key model assumptions and the applicability against the generic sources of model uncertainty. The licensee explained that in order to ensure the selected sensitivity cases adequately address the uncertainty from key assumptions, those sources of uncertainty with the potential to challenge the acceptance criteria for candidate STI changes, would be evaluated with additional sensitivity studies during the TSTF-425, Revision 3, implementation in accordance with NEI 04-10, Revision 1. Because the licensee confirmed that the key assumptions in the LERF analysis will be reviewed in accordance with the NRC-approved NEI 04-10, Revision 1, the NRC staff concludes that this F&O has no impact on the use of the PRA for changes to the surveillance frequencies in the SFCP.

The 2017 focused-scope peer review team created F&O RB-6106, related to internal flooding Supporting Requirement IFQU-A5, which identified that a consistency check of the internal flooding human error probabilities (HEPs) was not performed. In its letter dated December 17, 2018, the licensee stated that a consistency check was performed for the internal flooding HEPs and that the HEPs were reasonable and consistent with similar operator actions in the analysis, given the context of the scenarios and plant operational practices, procedures, and experience.

Because the licensee confirmed that it performed internal flooding HEP consistency evaluations and found the HEPs acceptable, the NRC staff concludes that this F&O has no impact on the proposed use of the PRA.

The 2017 focused-scope peer review team created F&O RB-6108, related to internal flooding Supporting Requirement IFQU-A7, which identified that the human failure events (HFE) values in the dependency analysis were not set (seeded) with sufficiently high values to ensure that cutsets with multiple HFEs were not truncated. In its letter dated December 17, 2018, the licensee explained that the HEPs for all operator actions were set to a sufficiently high value and that this F&O has no impact on the application. Based on the information provided, the NRC staff concludes that the licensee has addressed the seeding of HEPs for the dependency analysis appropriately for the proposed use of the PRA.

The 2017 focused-scope peer review team created F&O RB-6110, related to internal flooding Supporting Requirement IFQU-B3, which identified that a review of sources of modeling uncertainty in the internal flooding PRA and its impact on the results was not performed. In its letter dated December 17, 2018, the licensee stated that a review of key model assumptions as well as the generic sources of model uncertainty was performed consistent with the guidance in NUREG-1855, Revision 1, "Guidance on the Treatment of Uncertainties Associated with PRAs in Risk-Informed Decisionmaking," dated March 2017 (Reference 20). The licensee stated that the sources of uncertainty will be used to identify candidate sensitivity analyses and assess those uncertainties that may impact the internal flooding analysis results. Because the licensee confirmed that it reviewed the key assumptions in the LERF analysis and will use those results to address impacts to the internal flooding analysis results, the NRC staff concludes that this F&O has no impact on the proposed use of the PRA.

Based on the preceding analysis, the NRC staff concludes that the licensee addressed the findings from the peer reviews and demonstrated that they have no significant impact on the technical adequacy of the PRA. Therefore, the NRC staff concludes that the licensee has evaluated its internal events PRA against the current ASME/ANS RA-Sa-2009 PRA standard and RG 1.200, Revision 2, and that the internal events, including internal flooding PRA model, is of sufficient technical adequacy to support the evaluation of changes to TS surveillance frequencies that are relocated to the SFCP.

3.1.4.2 Scope of the PRA In accordance with NEI 04-10, Revision 1, the licensee should evaluate each proposed change to a relocated surveillance frequency to determine the change's potential impact on risk (CDF and LERF) from internal events, fires, seismic, other external events, and at shutdown conditions. In cases where a PRA of sufficient scope or quantitative risk models are unavailable, the licensee may use bounding analyses, or other conservative quantitative evaluations. A qualitative screening analysis may be used when the surveillance frequency impact on plant risk is shown to be negligible or zero.

The licensee has full-power internal events and internal floods PRA models. These models received peer reviews as discussed in SE Section 3.1.4.1. As required by proposed TS 5.5.12 and in accordance with NEI 04-10, Revision 1, the licensee will use these models to perform quantitative evaluations to support the development of changes to surveillance frequencies in the SFCP.

RBS does not have PRA models for internal fires, seismic events, external flooding, high winds, and other external hazards (e.g. transportation, nearby facility accidents, etc.). As required by proposed TS 5.5.12 and in accordance with NEI 04-10, Revision 1, the licensee will perform an initial qualitative screening analysis, and, if the qualitative information is not sufficient to provide confidence that the net impact of the STI change would be negligible, a bounding analysis will be performed. In its letter dated December 17, 2018, the licensee stated that qualitative assessment of external hazards will assess available Individual Plant Examination of External Events information to determine the impact on proposed STI changes, consistent with Step 1 Oa of the NEI 04-10 methodology. The licensee stated that insights may also be obtained from the fire safe shutdown analysis and risk management actions for managing fire risk. In addition, bounding analyses for STI changes will be performed in accordance with Step 1 Ob of NEI 04-10, Revision 1.

Additionally, the licensee stated that the evaluation of fire risk and other external events risk supporting the SFCP will reflect and consider the current plant configuration and operating experience. The licensee states that for applicable STI change evaluations, qualitative evaluation of fire and external events risk in support of Step 1 Ob would include consideration of applicability to the current plant configuration and operating experience. The licensee will document this information for each STI change provided to the Integrated Decision Panel.

Based on the above considerations, the NRC staff finds the licensee's treatment of external events acceptable. In addition, the staff concludes that through the application of NRG-approved NEI 04-10, Revision 1, per proposed TS 5.5.12, the licensee's evaluation methodology is sufficient to ensure the scope of the risk contribution of each surveillance frequency change is properly identified for evaluation, and is consistent with Regulatory Position 2.3.2, "Scope of the Probabilistic Risk Assessment for Technical Specification Change Evaluations," of RG 1.177, Revision 1.

3.1.4.3 PRA Modeling The LAR (Reference 1) states that its SFCP methodology includes a determination of whether the SSCs affected by a proposed change to a surveillance frequency are modeled in the PRA.

Where the SSC is directly or implicitly modeled, a quantitative evaluation of the risk impact may be carried out. The methodology adjusts the failure probability of the impacted SSCs, including any impacted common cause failure modes based on the proposed change to the surveillance frequency. Where the SSC is not modeled in the PRA, bounding analyses are performed to characterize the impact of the proposed change to the surveillance frequency. Potential impacts on the risk analyses due to screening criteria and truncation levels are addressed by the requirements for PRA technical adequacy, consistent with guidance contained in RG 1.200, Revision 2, and by sensitivity studies identified in NEI 04-10, Revision 1.

The NRC staff concludes that through the application of NRG-approved NEI 04-10, Revision 1, which would be required by proposed TS 5.5.12, the PRA modeling is sufficient to ensure an acceptable evaluation of risk for the proposed changes in surveillance frequency, and is consistent with Regulatory Position 2.3.3, "Probabilistic Risk Assessment Modeling," of RG 1.177, Revision 1.

3.1.4.4 Assumptions for Time Related Failure Contributions The failure probabilities of SSCs modeled in PRAs may include a standby time-related contribution and a cyclic demand-related contribution. The adjustment criteria in NEI 04-10, Revision 1, adjust the time-related failure contribution of SSCs affected by the proposed change to a surveillance frequency. This is consistent with RG 1.177, Revision 1, Section 2.3.3, which permits separation of the failure rate contributions into demand and standby for evaluation of surveillance requirements. In addition, the process described by NEI 04-10, Revision 1, which would be imposed by TS 5.5.12, includes consideration of qualitative sources of information with regard to potential impacts of test frequency on SSC performance, including industry and plant-specific operating experience, vendor recommendations, industry standards, and code-specified test intervals. Thus, the NRC staff concludes that risk analyses and other information will be used.

The NRC staff concludes that through the application of NRG-approved NEI 04-10, Revision 1, the licensee will employ reasonable assumptions with regard to any extensions of STI, and is consistent with Regulatory Position 2.3.4, "Assumptions in Completion Time and Surveillance Frequency Evaluations," of RG 1.177, Revision 1.

3.1.4.5 Sensitivity and Uncertainty Analyses Proposed TS 5.5.12 would require that changes to frequencies listed in the SFCP be made in accordance with NEI 04-10, Revision 1. Therefore, the licensee would be required to use sensitivity studies to assess the impact of uncertainties from key assumptions of the licensee's PRA, uncertainty in the failure probabilities of the affected SSCs, impact on the frequency of initiating events, and any identified deviations from Capability Category II of the ASME/ANS RA-Sa-2009 PRA standard. Where the sensitivity analyses identify a potential impact on the proposed change, revised surveillance frequencies are considered, along with any qualitative considerations that may bear on the results of such sensitivity studies. The licensee would also perform necessary monitoring and feedback of SSC performance once the revised surveillance frequencies are implemented. Thus, through the application of NRG-approved NEI 04-10, Revision 1, the licensee will appropriately consider the possible impact of PRA model uncertainty and sensitivity to key assumptions and model limitations, consistent with Regulatory Position 2.3.5, "Sensitivity and Uncertainty Analyses Relating to Assumptions in Technical Specification Change Evaluations," of RG 1.177, Revision 1.

3.1.4.6 Acceptance Guidelines In accordance with the proposed TS 5.5.12, under its SFCP the licensee would quantitatively evaluate the change in total risk (including internal and external events contributions) in terms of CDF and LERF using the guidance contained in NRG-approved NEI 04-10, Revision 1. The qualitative evaluation will include both the individual risk impact of a proposed change in surveillance frequency, and the cumulative impact from all individual changes to surveillance frequencies. In accordance with the acceptance criteria in RG 1.174, Revision 3, for very small changes in risk, each individual change to surveillance frequency must show a risk increase below 1 E-6 per year for CDF, and below 1 E-7 per year for LERF or the process terminates without permitting the proposed changes. Where quantitative results are unavailable for comparison with the acceptance guidelines, appropriate qualitative analyses are used to demonstrate that the associated risk impact of a proposed change to surveillance frequency is negligible. Otherwise, bounding quantitative analyses are used to demonstrate the risk impact is at least one order of magnitude lower than the acceptance criteria in RG 1.17 4 for very small changes in risk. In addition to assessing each individual SSC surveillance frequency change, the proposed SFCP would ensure that cumulative impact of all changes result in a risk increase less than 1 E-5 per year for CDF, and less than 1 E-6 per year for LERF. Further, proposed TS 5.5.12 would ensure that the total CDF and total LERF must be reasonably shown to be less than 1 E-4 per year and 1 E-5 per year, respectively. The NRC staff finds that these values are consistent with the acceptance criteria of RG 1.17 4, Revision 3, as referenced by RG 1.177, Revision 1, for changes to surveillance frequencies.

Consistent with the NRC safety evaluation dated September 19, 2007, on NEI 04-10, Revision 1, proposed TS 5.5.12 will require the licensee to calculate the total change in risk (i.e.,

the cumulative risk) by comparing a baseline model that uses failure probabilities based on surveillance frequencies prior to being changed per the SFCP to a revised model that uses failure probabilities based on the changed surveillance frequencies. The staff further notes that NEI 04-10, Revision 1, includes a provision to exclude the contribution to cumulative risk from individual changes to surveillance frequencies associated with insignificant risk increases (i.e.,

less than 5E-8 CDF and 5E-9 LERF) once the baseline PRA models are updated to include the effects of the revised surveillance frequencies.

The quantitative acceptance guidance of RG 1.17 4, Revision 3, is supplemented by qualitative information to evaluate the proposed changes to surveillance frequencies, including industry and plant-specific operating experience, vendor recommendations, and industry standards, or at least bounding, quantitative results of sensitivity studies and SSC performance data and test history. The final acceptability of the proposed change is based on all of these considerations and not solely on the PRA results. Post-implementation performance monitoring and feedback are also required to assure continued reliability of the SSC's. The licensee's application of NEI 04-10 provides acceptable methods for evaluating the risk increase associated with proposed changes to surveillance frequencies, consistent with Regulatory Position 2.4, "Acceptance Guidelines for Technical Specification Changes," of RG 1.177, Revision 1.

Therefore, the NRC staff finds that the licensee's proposed methodology satisfies the fourth key safety principle of RG 1.177, Revision 1, by assuring any increase in risk is small consistent with the intent of the Commission's Safety Goal Policy Statement.

3.1.5 The Impact of the Proposed Change Should Be Monitored Using Performance Measurement Strategies The licensee's proposed TS 5.5.12 requires the application of NEI 04-10, Revision 1, in the SFCP. The guidance in NEI 04-10 includes performance monitoring of SSCs whose surveillance frequencies have been revised as part of a feedback process to assure that any change in test frequency has not resulted in degradation of equipment performance and operational safety. The monitoring and feedback includes consideration of monitoring of equipment performance required by the Maintenance Rule (10 CFR 50.65). In the event of degradation of SSC performance, the surveillance frequency will be reassessed in accordance with the methodology, in addition to any corrective actions that may apply as part of the maintenance rule requirements. The performance monitoring and feedback specified in NEI 04-10, Revision 1, is sufficient to assure acceptable SSC performance and is consistent with Regulatory Position 3.2, "Maintenance Rule Control," of RG 1.177, Revision 1. Thus, the NRC staff concludes that the fifth key safety principle of RG 1.177, Revision 1, is satisfied.

3.2 Limitations and Conditions The NRC staff's SE in response to NEI 04-10, Section 4.0, states that:

The NRC staff finds that the methodology in NEI 04-10, Revision 1 is acceptable for referencing by licensees proposing to amend their TSs to establish a SFCP provided the following conditions are satisfied:

1. The licensee submits documentation with regards to PRA technical adequacy consistent with the requirements of RG 1.200, Section 4.2.

2. When a licensee proposes to use PRA models for which NRG-endorsed standards do not exist, the licensee submits documentation which identifies the quality characteristics of those models, consistent with RG 1.200 Sections 1.2 and 1.3. Otherwise, the licensee identifies and justifies the methods to be applied for assessing the risk contribution for those sources of risk not addressed by PRA models.

Section 3.1.4.1 of this SE discusses the technical adequacy of the licensee's PRA model and finds it to be consistent with NRG-endorsed guidance. As discussed in Section 3.1.4.1 the NRC staff finds the information supplied in the LAR, as supplemented, supports the licensee's proposed PRA and therefore the limitations in the NRC staff's SE related to NEI 04-10 have been met.

3.3 Addition of Surveillance Frequency Control Program to Administrative Controls The licensee proposed to include the SFCP and specific requirements into the RBS TS 5.5.12, as follows:

Surveillance Frequency Control Program This program provides controls for Surveillance Frequencies. The program shall ensure that Surveillance Requirements specified in the Technical Specifications are performed at intervals sufficient to assure the associated Limiting Conditions for Operation are met.

a.

The Surveillance Frequency Control Program shall contain a list of Frequencies of those Surveillance Requirements for which the Frequency is controlled by the program.

b.

Changes to the Frequencies listed in the Surveillance Frequency Control Program shall be made in accordance with NEI 04-10, "Risk-Informed Method for Control of Surveillance Frequencies," Revision 1.

c.

The provisions of Surveillance Requirements 3.0.2 and 3.0.3 are applicable to the Frequencies established in the Surveillance Frequency Control Program.

Based on its review in the sections above, the NRC staff concludes that the SFCP is an acceptable program to list surveillance frequencies and control changes to surveillance frequencies. The staff further finds that proposed TS 5.5.12 includes the necessary program and applicability requirements, that those requirements are consistent with the TSTF-425, Revision 3, and that those requirements will ensure that LCOs are met. Therefore, the NRC staff finds proposed TS 5.5.12 acceptable.

3.4 Deviations from TSTF-425 and Other Changes 3.4.1 Definition of Staggered Test Basis The definition of STAGGERED TEST BASIS is being retained in the RBS TSs due to its continued use in several SR frequencies, which are not the subject of this LAR (e.g.,

SRs 3.4.4.3, 3.5.1.7, and 3.6.1.6.1 ). This is an administrative deviation and the NRC staff concludes that the definition should be retained to inform the SRs that use the definition and that remain the TS. Therefore, the staff finds this deviation acceptable.

3.4.2 Variation in TS Surveillance Requirement Numbering The RBS SRs numbering differs from the corresponding TSTF-425 SRs. The NRC staff finds that the SR numbering variations are editorial and non-substantive deviations from TSTF-425 that are consistent with the TS numbering scheme at RBS. Therefore, the NRC staff concludes that these deviations are acceptable.

3.4.3 Comparison of SR Changes between the RBS TSs and NUREG-1434 TSs The licensee stated that NUREG-1434 contains SRs that are not in the RBS TSs. The NRC staff reviewed the variations from the STSs in NUREG-1434 and determined that, because the omitted SRs were previously found to be inapplicable to RBS when it converted to the STSs, these deviations are consistent with currently approved RBS TSs. Therefore, the staff finds these variations acceptable.

The licensee stated that plant-specific SRs are not included in TSTF-425. These SRs were added to the RBS TSs per Amendment No. 188 (Reference 21), which implements TSTF-523, Revision 2, "Generic Letter 2008-01, Managing Gas Accumulation." TSTF-523 allows the option of relocating the applicable SRs to the Surveillance Frequency Control Program (SFCP).

The licensee stated that the RBS plant-specific SRs involve fixed periodic frequencies and do not meet any of the four exclusion criteria of TSTF-425. The NRC staff reviewed the proposed plant-specific SRs listed in Section 2.2 of the LAR and concludes that relocation of the plant-specific SR frequencies is consistent with TSTF-425, and the plant-specific SRs do not meet any of the exclusions identified in Section 1.0, "Introduction," of the NRC staff's model SE dated July 6, 2009. Therefore, the staff finds these variations acceptable.

The licensee proposed to add the SFCP to TS Section 5.5.12 instead of adding the program to the end of TS Section 5.5, as indicated in the NRC staff's model SE dated July 6, 2009.

Additionally, the licensee would remove the word "deleted" currently in TS Section 5.5.12. This change requires formatting changes that move applicable portions of the text as identified in the licensee's markup of the TS pages. The licensee considers the deviations to be administrative deviations from TSTF-425, Revision 3, that do not affect the substantive conclusions in the NRC's model SE dated July 6, 2009. The NRC staff evaluated the deviations and determined that differences from TSTF-425 are not substantive and do not affect the acceptability of the SFCP. Therefore, the NRC staff finds these deviations to be acceptable.

3.4.4 Control Room Envelope Habitability Program The licensee proposed to revise TS 5.5.14.d as follows (deleted text in strikeout and added text in italics):

Measurement, at designated locations, of the CRE pressure... by one subsystem of the CRFA [Control Room Fresh Air] System... at a Frequency of 24 months on a STAGGERED TEST BASIS in accordance with the Surveillance Frequency Control Program. The results shall be trended and used as part of the 24 month assessment of the CRE [control room envelope] boundary assessment specified in 5.5.14.c (ii).

The licensee adopted TSTF-448, "Control Room Habitability," in Amendment No. 154 (Reference 22), which revised the SRs to perform control room envelope unfiltered air leakage testing in accordance with the Control Room Envelope Habitability Program. The licensee designated the Control Room Envelope Habitability Program as TS 5.5.14 and the subject SR as TS 5.5.14.d. The SR revised under TSTF-448 for Standard Technical Specifications (under NUREG-1434) was designated as SR 3.7.3.4. TSTF-425 includes relocation of the frequency for SR 3.7.3.4 to the SFCP. The licensee proposed to adopt the frequency change identified for NUREG-1434 SR 3.7.3.4 for RBS as TS 5.5.14.d.

The NRC staff reviewed the proposed changes and determined that reflecting the relocation of the SR frequency in STS SR 3.7.3.4 in TSTF-425, by modifying RBS TS 5.5.14.d continues to require that the CRE unfiltered air leakage testing specified in SR 5.5.14.d is performed as required by the Control Room Envelope Habitability Program. Also, the frequency currently referenced in TS 5.5.14.d is a periodic frequency that does not meet the exclusion criteria in TSTF-425, and relocation of the frequency is consistent with the intent of TSTF-425, Revision 3.

Therefore, the NRC staff finds the proposed changes to TS 5.5.14.d acceptable.

3.4.5 Administrative Control Programs SR Frequencies The licensee proposed changes to SR frequencies in TS 5.5. 7, "Ventilation Filter Testing Program (VFTP)," and TS 5.5.9, "Diesel Fuel Oil Testing Program," related to total particulate concentration of the fuel oil in the storage tanks that are not identified for relocation in TSTF-425, Revision 3 because they are plant-specific TSs. The changes would replace the specific frequency requirements in this TSs with "in accordance with the Surveillance Frequency Control Program." The staff reviewed the licensee's proposed changes to relocate these SRs and determined that the SR frequencies do not meet the exclusion criteria of TSTF-425, Revision 3, that the frequencies are fixed periodic frequencies, and that relocation of these frequencies is consistent with the intent of this TSTF. Therefore, the NRC staff finds that relocation of these plant-specific TS SR frequencies to the SFCP is acceptable.

3.4.6 Combined Unit Power Supplies SR The licensee proposed to revise SR 3.8.1.8 to correct a formatting error. Currently, SR 3.8.1.8.a and SR 3.8.1.8.b are listed within the same SR row, each with a frequency specified as 24 months. The proposed amendment would modify SR 3.8.1.8 to combine the two SRs into a single SR with two sub-activities and one frequency (i.e., in accordance with the SFCP). The licensee proposed the following changes to SR 3.8.1.8:

Verify, for required unit power supplies:

a. Manual transfer of unit power supply from the normal offsite circuit to required alternate offsite circuit; and

b. Automatic transfer of bus E22-S004 through NNS-SWG1A or NNS-SWG1 B from the 22 kV onsite circuit to required offsite circuit.

The NRC staff reviewed the proposed changes to SR 3.8.1.8 and determined that combining SR 3.8.1.8.a and b. to share one frequency is consistent with the current SR and will ensure that the 10 CFR 50.36(c)(3) requirement that the TSs include requirements relating to test, calibration or inspection to assure that the necessary quality of systems and components is maintained, that the facility operation will be within safety limits and the limiting conditions for operation will be met.. Further, this change is consistent with the formatting of similar SRs in the RBS TS (e.g., SRs 3.8.1.7, 3.8.1.11, and 3.8.1.12) and would improve the readability of the TSs by using consistent formatting. Therefore, the NRC staff finds these changes acceptable.

3.4. 7 Repagination of TS Pages Due to the relocation and modification of SR frequencies, there were multiple SRs that moved to the next page. The licensee proposed the following changes:

Add pages 3.3-6a, 3.3-52a, 3.5-5a, 5.0-16b; Replace current page 3.8-16 with new page 3.8-16 to accommodate the SRs that move to the next page; Delete from current page 3.8-16 the text, "Table 3.8.1-1 has been deleted";

Delete rows for SRs 3.6A.1. 7 and 3.8.3.6 because the associated SRs were deleted; and Minor formatting corrections.

The NRC staff reviewed the proposed changes and determined that the formatting and pagination changes identified in the markup of the TS pages are minor deviations from TSTF-425, are consistent with existing RBS TSs, and do not affect the acceptability of the SFCP and relocation of SR frequencies as evaluated in the NRC's model SE dated July 6, 2009. Therefore, the NRC staff finds the proposed changes acceptable.

3.5 Summary and Conclusions The NRC staff reviewed the licensee's proposed relocation of certain surveillance frequencies to a licensee-controlled document, proposal to control changes to surveillance frequencies in accordance with a new program, the SFCP, which is required by TS 5.5.12. The NRC staff confirmed that this amendment adheres to the TSTF-425 exclusion criteria in that it does not relocate surveillance frequencies that are specified by other approved programs, are purely event-driven, are event-driven but have a time component for performing the surveillance on a one-time basis once the event occurs, or are related to specific conditions.

The proposed adoption of TS changes consistent with TSTF-425, Revision 3, and the risk-informed methodology of NRG-approved NEI 04-10, Revision 1, as referenced in TS 5.5.12 of the Administrative Controls section of the RBS TSs, satisfies the key principles of risk-informed decision making as delineated in RG 1.177, Revision 1 and RG 1.17 4, Revision 3 in that:

The proposed changes meet current regulations; The proposed changes are consistent with defense-in-depth philosophy; The proposed changes maintain sufficient safety margins; Increases in risk resulting from the proposed changes are small and consistent with the Commission's Safety Goal Policy Statement; and The impact of proposed change will be monitored with performance measurement strategies.

The proposed adoption of TS changes in TS Sections 3 and 5 are consistent with TSTF-425, Revision 3, and the use of NEI 04-01, as required by proposed TS 5.5.12, also meets the limitations and conditions in the NRC staff's SE on NEI 04-10.

Section 50.36(c) of 10 CFR specifies the categories that must be included in the TSs.

Section 50.36(c)(3) states, Surveillance requirements 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.

Based on the above evaluation, the NRC staff concludes that, the proposed relocation of surveillance frequencies to a licensee-controlled document, the SFCP, which is controlled by the TS 5.5.12 requirement that the program ensure surveillance frequencies assure that LCOs are met and any changes to those frequencies are appropriate under NEI 04-10, the licensee continues to meet the requirements in 10 CFR 50.36( c)(3).

4.0 STATE CONSULTATION

In accordance with the Commission's regulations, the Louisiana State official was notified of the proposed issuance of the amendment on March 6, 2019. The State official had no comments.

5.0 ENVIRONMENTAL CONSIDERATION

This amendment changes a requirement with respect to installation or use of facility components located within the restricted area as defined in 10 CFR Part 20 and involves changes to 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 Commission has previously issued a proposed finding that the amendment involves no significant hazards consideration published in the Federal Register on May 22, 2018 (83 FR 23733), and there has been no public comment on such finding. The amendment also changes a recordkeeping, reporting or administrative procedures or requirements and makes editorial or other minor corrective changes. Accordingly, this amendment meets the eligibility criteria for categorical exclusion set forth in 10 CFR 51.22(c)(9) and ( c )( 10 ). Pursuant to 10 CFR 51.22(b ), no environmental impact statement or environmental assessment need be prepared in connection with the issuance of this 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 Commission's 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.

7.0 REFERENCES

1.

Maguire, W. F., Entergy Operations, Inc., letter to U.S. Nuclear Regulatory Commission, "Application for Technical Specification Change Regarding Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program (TSTF-425), River Bend Station, Unit 1, Docket No. 50-458, License No. NPF-47," dated February 28, 2018 (Agencywide Documents Access and Management System (ADAMS) Accession No. ML18067A115).

2.

Schenk, T., Entergy Operations, Inc., letter to U.S. Nuclear Regulatory Commission, "Supplement to Application for Technical Specification Change Regarding Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program (TSTF-425), River Bend Station, Unit 1, Docket No. 50-458, License No. NPF-47," dated July 10, 2018 (ADAMS Accession No. ML181918010).

3.

Schenk, T., Entergy Operations, Inc., letter to U.S. Nuclear Regulatory Commission, "Supplement to Application for Technical Specification Change Regarding Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program (TSTF-425), River Bend Station, Unit 1, Docket No. 50-458, License No. NPF-47," dated July 24, 2018 (ADAMS Accession No. ML18205A520).

4.

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5.

Reynolds, J. W., Entergy Operations, Inc., letter to U.S. Nuclear Regulatory Commission, "Supplement to Application for Technical Specification Change Regarding Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee Controlled Program (TSTF-425), River Bend Station, Unit 1, NRC Docket No. 50-458, Facility Operating License No. NPF-47," dated December 20, 2018 (ADAMS Accession No. ML19002A115).

6.

Technical Specifications Task Force, letter and enclosure to U.S. Nuclear Regulatory Commission, "Transmittal of TSTF-425, Revision 3, 'Relocate Surveillance Frequencies to Licensee Control-RITSTF Initiative 5b,"' dated March 18, 2009 (ADAMS Accession No. ML090850642).

7.

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8.

Nieh, H. K., U.S. Nuclear Regulatory Commission, letter to Biff Bradley, Nuclear Energy Institute, "Final Safety Evaluation for Nuclear Energy Institute (NEI) Topical Report (TR} 04-10, Revision 1, 'Risk-Informed Technical Specifications Initiative 5b, Risk-Informed Method for Control of Surveillance Frequencies,' (TAC No. MD6111),"

dated September 19, 2007 (ADAMS Accession No. ML072570267).

9.

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10.

U.S. Nuclear Regulatory Commission, "An Approach for Plant-Specific, Risk-Informed Decisionmaking: Technical Specifications," Regulatory Guide 1.177, Revision 1, dated May 2011 (ADAMS Accession No. ML100910008).

11.

U.S. Nuclear Regulatory Commission, "An Approach for Determining the Technical Adequacy of Probabilistic Risk Assessment Results for Risk-Informed Activities,"

Regulatory Guide 1.200, Revision 2, dated March 2009 (ADAMS Accession No. ML090410014).

12.

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NUREG-0800, Section 19.2, dated June 2007 (ADAMS Accession No. ML071700658).

13.

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14.

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15.

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16.

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17.

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PRA Standard ASME/ANS RA-Sa-2009, "Addenda to ASME RA-S-2008, Standard for Level 1/Large Early Release Frequency Probabilistic Risk Assessment for Nuclear Power Plant Applications," February 2009, New York, NY

18.

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19.

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20.

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21.

Wang, A. B., U.S. Nuclear Regulatory Commission, letter to Vice President, Operations, Entergy Operations, Inc., "River Bend Station, Unit 1 - Issuance of Amendment Re:

Adoption of Technical Specification Task Force Traveler TSTF-523, "Generic Letter 2008-01, Managing Gas Accumulation" (TAC No. MF4782), dated September 21, 2015 (ADAMS Accession No. ML15195A061)

22.

Kalyanam N., for Vaidya, B., U.S. nuclear Regulatory Commission, letter to Mr. Joseph E. Venable, Operations, Entergy Operations, Inc., "River Bend Station, Unit 1 - Issuance of Amendment Re: Adoption of Technical Specifications Task Force (TSTF)-448, Revision 3, "Control Room Envelope Habitability, "Using Consolidated Line Item Improvement Process (TAC No. MD6108) dated November 16, 2007 (ADAMS Accession No. ML072490080)

Principal Contributors: Michael Levine Tarico Sweat Lisa Regner Date: April 29, 2019

SUBJECT:

RIVER BEND STATION, UNIT 1 - ISSUANCE OF AMENDMENT RE:

ADOPTION OF TECHNICAL SPECIFICATIONS TASK FORCE TRAVELER TSTF-425, REVISION 3 (EPID L-2018-LLA-0056) DATED APRIL 29, 2019 DISTRIBUTION:

PUBLIC PM File Copy RidsACRS_MailCTR Resource RidsNrrDeEeob Resource RidsNrrDeEicb Resource RidsNrrDeEmib Resource RidsNrrDmlrMccb Resource RidsNrrDorllpl4 Resource RidsNrrDraApla Resource RidsNrrDssScpb Resource RidsNrrDssSrxb Resource RidsNrrDssStsb Resource RidsNrrLAPBlechman Resource RidsNrrPMRiverBend Resource ADAMS A ccess1on N ML19066A008

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OFFICE NRR/DORL/LPL4/PM NRR/DORL/LPL4/LA NAME LRegner (GMiller for)

PBlechman DATE 4/29/2019 4/26/2019 OFFICE NRR/DSS/SCPB/BC** NRR/DSS/SRXB/BC**

NAME SAnderson JWhitman DATE 4/5/2019 4/2/2019 OFFICE NRR/DE/EMIB/BC**

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OFFICE NRR/DORL/LPL4/PM MO'Banion (GMiller NAME for)

DATE 4/29/2019 RidsRgn4MailCenter Resource RAlvarado, NRR RBeaton, NRR MBiro, NRR GCurran, NRR AFoli, NRR PKlein, NRR Mlevine, NRR TSweat, NRR ITseng, NRR MYoder, NRR LRegner, NRR EMiller, NRR

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v t e Letter Sequence Approval
EPID:L-2018-LLA-0056, TSTF-425 (Approved, Closed)
Initiation Request, Request Acceptance Supplement Administration Questions 31 October 2018 Answers 17 December 2018 Results Approval Other:
MONTHYEAR2018-12-20 [Table View]

ML19066A008

Text

SUBJECT:

Dear Sir or Madam:

Enclosures:

Attachment:

1.0 INTRODUCTION

2.1 REGULATORY EVALUATION

3.0 TECHNICAL EVALUATION

4.0 STATE CONSULTATION

5.0 ENVIRONMENTAL CONSIDERATION

6.0 CONCLUSION

7.0 REFERENCES

SUBJECT:

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