Text

Renewed Facility Operating License NPF-47 Attachments and Appendices
	ML18284A370
Person / Time
Site:	River Bend
Issue date:	12/20/2018
From:	Sayoc E; NRC/NRR/DMLR/MRPB
To:	; Entergy Operations
	nrr/dmlr
References
	Download: ML18284A370 (410)
	v • d • e

LICENSE AUTHORITY FILE COPY ATTACHMENT 1 TO-NPF 47 Prior to achieving the condition indicated on or before the date indicated, the following items shall be completed to the satisfaction of Region IV;

1. OUTSTANDING ITEMS TO BE ACCOMPLISHED PRIOR TO COMPLETION OF THE INITIAL TEST PROGRAM

a. Verify the station electric distribution voltage analyses are in accordance with the guidelines of Branch Technical Position PSB-1, Position 4.

b. Perform an engineering evaluation and complete modifications on the battery powered lighting system used in areas of the plant outside the main control room required for safe shutdown and personnel evacuation to upgrade those areas identified as deficient with regard to the requirements contained in FSAR Table 9.5-2.

2. OUTSTANDING ITEM TO BE COMPLETED PRIOR TO THE FIRST REFUELING OUTAGE

a. Complete and have operational the fuel building sampling system.

Off-loading of irradiated fuel prior to the first refueling outage shall be performed as described in GSU's letter dated June 13, 1985.

3. OUTSTANDING ITEM TO BE COMPLETED PRIOR TO FIRST DESIGN USE OR PRIOR TO STARTUP FOLLOWING THE FIRST REFUELING OUTAGE (WHICHEVER IS FIRST)

a. Complete a load test which meets all the OSHA requirements for load handling capability on all remaining cranes and hoists not previously tested.

4. OUTSTANDING ITEMS TO BE ACCOMPLISHED PRIOR TO STARTUP FOLLOWING THE FIRST REFUELING OUTAGE

a. Repair or replace the control valves on HVAC chillers as delineated in the 10 CFR 50.55(e) report identified as DR-314.

5. OUTSTANDING ITEM TO BE ACCOMPLISHED BY MAY 31, 1988

a. Complete installation of equipment improvements to the security radio communications system.

6. OUTSTANDING ITEM TO BE ACCOMPLISHED PRIOR TO START-VP FOLLOWING A SUBSEQUENT OUTAGE WITH A PLANNED DURATIO OF SEVEN DAY ORLNGER FOLLOWING MAY 31, 1988

a. Conduct testing to determine if adequate radio communication capability exists from appropriate plant areas.

7. OUTSTANDING ITEM TO BE ACCOMPLISHED PRIOR TO START-UP FOLLOWING THE SECOND REFUELING OUTAGE

a. If during acceptance testing it is determined that further modifica-tions and/or testing are required, this shall be performed during a subsequent outage of sufficient duration but prior to start-up following the second refueling outage.

~TC~'t"rSc .,on"-pY FILE COpS' DO iVEIV' ATTACHMENT 2 TO NPF-47 SEISMIC AND DYNAMIC QUALIFICATION OF SEISMIC CATEGORY I MECHANICAL AND ELECTRICAL EQUIPMENT EOI shall complete the following requirements for seismic and dynamic I qualification on the schedule noted below:

1. EOI shall complete the seismic qualification of the in-vessel rack I prior to its use.

Amendment No. 0,79 JUN 8 1993

ATTACHMENT 3 TO NPFI47 DELETED I Amendment No. 7,79,0£,102 JAN 2 7 1999

LICENSE AUTHORITY FILE COP% JD")NtOT RE`OVtE ATTACHMENT 4 TO NPF-47 FIRE PROTECTION PROGRAM REQUIREMENTS EOI shall comply with the following requirements of the fire protection I program:

EOI shall implement and maintain in effect all provisions I1.

of the I approved fire protection program as described in the Final Safety Analysis Report for the facility through Amendment 22 and as approved in the SER dated May 1984 and Supplement 3 dated August 1985 subject to provisions 2 and 3 below.

2. EOI may make no change to the approved fire protection program which I would significantly decrease the level of fire protection in the plant without prior approval of the Commission. To make such a change EOI must submit an application for license amendment pursuant I to 10 CFR 50.90.

3. EOI may make changes to features of the approved fire protection program which do not significantly decrease the level of fire protection without prior Commission approval provided (a) such changes do not otherwise involve a change in a license condition or technical specification or result in an unreviewed safety question (see 10 CFR 50.59), and (b) such changes do not result in failure to complete the fire protection program approved by the Commission prior to license issuance. EOI shall maintain, in an auditable form, a current record of all such changes, including an analysis of the effects of the change on the fire protection program, and shall make such records available to NRC inspectors upon request. All changes to the approved program shall be reported to the Director of the Office of Nuclear Reactor Regulation, along with the FSAR revisions required by 10 CFR 50.71(e).

Amendment No. O4,79 JUN 8 1995

LjCENqF AI ITLORITY FILE -COP! Do NO1 RECVE ATTACHMENT 5 TO NPF-47 EMERGENCY RESPONSE CAPABILITIES EOI shall complete the following requirements of NUREG-0737 Supplement No. I on the schedule noted below:

1. Actions and schedules for correcting all human engineering discrepancies (HEDs) identified in the 'Detailed Control Room Design Review Summary Report" dated October 31, 1984 and Supplements dated May 14, June 12, 1985, and July 31, 1985, shall be implemented in accordance with the schedule committed to by GSU in the summary report and supplements and accepted by the NRC staff in Section 18.1 of SSER 3.

2. Prior to startup following the first refueling outage, GSU shall implement modifications (installation or upgrade) for those items listed below consistent with the guidance of Regulatory Guide 1.97, Revision 2 unless prior approval of an alternate design of these items is granted by the NRC staff. These items as listed in GSU's letter of June 24, 1985 are:

a) coolant level in the reactor; b) suppression pool water level; c) drywell atmosphere temperature; d) primary system safety relief valve position; e) standby liquid control system storage tank level; f) emergency ventilation damper position; and g) airborne radiohalogens and particulates.

3. EOI shall implement modifications (installations or upgrade) for neutron flux monitoring consistent with the guidance of Regulatory Guide 1.97, Revision 2 or the NRC Staff's Safety Evaluation Report of the BWR Owners Group Licensing Topical Report (NEDO-31558, Position on NRC Regulatory Guide 1.97, Revision 3, Requirements for Post-Accident Neutron Monitoring System). Modifications, if required, shall be completed before restart from the next refueling outage starting after 18 months from the date of receipt of the NRC Staff Evaluation Report on NEDO-31558, but no later than startup from refueling outage No. 4 unless otherwise notified in writing by the NRC staff.

Amendment No. UG,79 JUN 8 1995

TABLE OF CONTENTS 1.0 USE AND APPLICATION ................ 1.0-1 1.1 Definitions . . . 1.0-1 1.2 Logical Connectors. 1.0-8 1.3 Completion Times ......... 1.0-11 1.4 Frequency . . . . . . . . .. . . . 1.0-24 2.0 SAFETY LIMITS (SLs) .............. 2.0-1 2.1 SLs . . . . . . . . . . . . . . . . . . . . 2.0-1 2.2 SL Violations . . . . . ... . . . . . . . . . . 2.0-1 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY 3.0-1 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY . . . . 1 3.0-4 3.1 REACTIVITY CONTROL SYSTEMS . . . . . . . . 3.1-1 3.1.1 SHUTDOWN MARGIN (SDM) . . . . . . . . . . . . . 3.1-1 3.1.2 Reactivity Anomalies . . . . . . . . . 3.1-4 3.1.3 Control Rod OPERABILITY . . . . . . . . . .. 3.1-6 3.1.4 Control Rod Scram Times . . . :. 3.1-11 3.1.5 Control Rod Scram Accumulators . . . . . . 3.1-15 3.1.6 Control Rod Pattern . . . . . . . . . 3.1-18 3.1.7 Standby Liquid Control (SLC) System 3.1-20 3.1.8 Scram Discharge Volume (SDV) Vent and Drain Valves . . . . . . . . . . . . . . . . ... ... 3.1-24 3.2 POWER DISTRIBUTION LIMITS . . . . . . ,... . 3.2-1 3.2.1 AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR) . . . . . . . . . . . . . . . . . . .... ... 3.2-1 3.2.2 MINIMUM CRITICAL POWER RATIO (MCPR) . . . . . . ... . .. 3.2-2 3.2.3 LINEAR HEAT GENERATION RATE (LHGR) . . . . . . . ... . .. 3.2-3 3.2.4 APRM Gain and Setpoints . . . . . . . . . . . . ... ... 3.2-4 3.3 TWZT0IIMFNTATTnN

.,.~ a I\Ui'LIR9" I A a ISU . . . . . . . . . . . . . . . . . . . . . . 3.3-1 3.3.1.1 Reactor Protection System (RPS) Instrumentation . . . . 3.3-1 3.3.1.2 Source Range Monitor (SRM) Instrumentation . . . . . . . 3.3-10 3.3.2.1 Control Rod Block Instrumentation . . . . . . . . . . . 3.3-15 3.3.3.1 Post Accident Monitoring (PAM) Instrumentation . . . . . 3.3-19 3.3.3.2 Remote Shutdown System .... .T pE C..R. .. 3.3-23 3.3.4.1 End of Cycle Recirculation Pump Trip (EkCRPT)

Instrumentation .. . .. 3.3-25 3.3.4.2 Anticipated Transient Without ScramRecirculation Pump Trip (ATWS-RPT) Instrumentation . . . . . . . . 3.3-29 3.3.5.1 Emergency Core Cooling System (ECCS)

Instrumentation .n . . .R. . ..Syse . . . . . . 3.3-32 3.3.5.2 Reactor Core Isolation Cooling (RCIC) y Instrumentation 3.3-44 3.3.6.1 Primary Containment anWdDrywellIsolatioinInstrumentation 3.3-48 3.3.6.2 Secondary Containment Isolation Instrumentation . 3.3-58 3.3.6.3 Containment Unit Cooler System Instrumentation . . . . . 3.3-62 (continued)

RIVER BEND i Revision No. 0

TABLE OF CONTENTS 3.3 INSTRUMENTATION (continued) 3.3.6.4 Relief and Low-Low Set (tLLS) Instrumentation . . . . . . 3.3-66 3.3.7.1 Control Room Fresh Air (CRFA) System Instrumentation . . .. . . . . . . . . . . ... . . 3.3-68 3.3.8.1 Loss of Power (LOP) Instrumentation . . . . . . . . . . 3.3-72 3.3.8.2 Reactor Protection System (RPS) Electric Power Monitoring . . . . . . . . . . . . . . . . . . . . . 3.3-75 3.4 REACTOR COOLANT SYSTEM (RCS) . . . . . . . . . . . . . 3.4-1 3.4.1 Recirculation Loops Operating . . . . . . . . . . 3.4-1 3.4.2 Flow Control Valves (FCVs) . . . . . . . . . . . . 3.4-6 3.4.3 Jet Pumps . . . . . . . . . . . . . . . . . . . . 3.4-8 3.4.4 Safety/Relief Valves (S/RVs) . . . . 3.4-10 3.4.5 RCS Operational LEAKAGE . . . . . . . . . . . . . 3.4-12 3.4.6 RCS Pressure Isolation Valve (PIV) Leakage . . 3.4-14 3.4.7 RCS Leakage Detection Instrumentation . . . . . . 3.4-17 3.4.8 RCS Specific Activity . . . . . . . . . . . . . . 3.4-20 3.4.9 Residual Heat Removal (RHR) Shutdown Cooling System-Hot Shutdown . . . . . . . . . . . .. 3.4-22 3.4.10 Residual Heat Removal (RHR) Shutdown Cooling System-Cold Shutdown 3.4-25 3.4.11 RCS Pressure and Temperature (P/T) Limits . 3.4-27 3.4.12 Reactor Steam Dome Pressure . . . . . . . . . . . . 3.4-33 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM . . . . . . . . . . . 3.5-1 3.5.1 ECCS-Operating . . . . . . . . . . . . . . . . . 3.5-1 3.5.2 ECCS-Shutdown . . . . . . . . . . . . . . . . . . 3.5-6 3.5.3 RCIC System ................... 3.5-10 3.6 CONTAINMENT SYSTEMS . . . . . . . ........... 3.6-1 3.6.1.1 Primary Containment-Operating . . . . . . . . . . . 3.6-1 3.6.1.2 Primary Containment Air Locks . . . . . . . . . . . 3.6-3 3.6.1.3 Primary Containment Isolation Valves (PCIVs) . . . . 3.6-9 3.6.1.4 Primary Containment Pressure . . . . . . . . . . . . 3.6-21 3.6.1.5 Primary Containment Air Temperature . . . . . . . . 3.6-22 3.6.1.6 Low-Low Set (LLS) Valves . . . . . . . . . . . . . . 3.6-23 3.6.1.7 Primary Containment Unit Coolers . . . . . . . . . . 3.6-25 3.6.1.8 Deleted . . . . . . . . . . . . . . 3.6-27 I 3.6.1.9 Main Steam-Positive Leakage Control System (MS-PLCS) 3.6-29 3.6.1.10 Primary Containment-Shutdown . . . . . . . . . . . . 3.6-31 3.6.2.1 Suppression Pool Average Temperature . . . . . . . . 3.6-33 3.6.2.2 Suppression Pool Water Level . . . . . . . . . . . . 3.6-36 3.6.2.3 Residual Heat Removal (RHR) Suppression Pool Cooling . . . . . . . . . . . . 3.6-37 3.6.3.1 Primary Containment Hydrogen Recombiners . . . 3.6-39 3.6.3.2 Primary Containment and Drywell Hydrogen Igniters 3.6-41 (continued)

RIVER BEND 1i Revision No. 4,1 AUG 2 6 1907

TABLE OF CONTENTS 3.6 CONTAINMENT SYSTEMS (continued) 3.6.3.3 Primary Containment/Drywell Hydrogen Mixing System 3.6-44 3.6.4.1 Secondary Containment-Operating . . 3.6-46 3.6.4.2 Secondary Containment Isolation Dampers (SCIDs) 3.6-48 3.6.4.3 Standby Gas Treatment (SGT) System . . . . .. . 3.6-51 3.6.4.4 Shield Building Annulus Mixing System . . . 3.6-53 3.6.4.5 Fuel Building 3.6-55 3.6.4.6 Fuel Building Ventilation System-Operating . 3.6-56 3.6.4.7 Fuel Building Ventilation System-Fuel Handling 3.6-58 3.6.5.1 Drywell . . . . . . . . . . . . . . . . . . . . . 3.6-60 3.6.5.2 Drywell Air Lock . . . . . . . . . . . . . . . . . 3.6-62 3.6.5.3 Drywell Isolation Valves . . . . . . . . . . . . . 3.6-67 3.6.5.4 Drywell Pressure . . . . . . . . . . . . . . . . . 3.6-71 3.6.5.5 Drywell Air Temperature . . . . . . . . . . . . . 3.6-72 3.7 PLANT SYSTEMS .......... 3.7-1 3.7.1 Standby Service Water (SSW) System and Ultimate Heat Sink (UHS) . . . . . . . 3.7-1 3.7.2 Control Room Fresh Air (CRFA) System . . . 3.7-5 3.7.3 Control Room Air Conditioning (AC) System 3.7-9 3.7.4 Main Condenser Offgas . . . . . . . . . . 3.7-12 3.7.5 Main Turbine Bypass System . . . . . . . . 3.7-14 3.7.6 Fuel Pool Water Level . . . . . . . . . . 3.7-15 3.8 ELECTRICAL POWER SYSTEMS . . . . . . . . . . . . . 3.8-1 3.8.1 AC Sources-Operating . . . . . . . . . . . . 3.8-1 3.8.2 AC Sources-Shutdown . . 3.8-17 3.8.3 Diesel Fuel Oil, Lube Oil, and Starting Air' 3.8-21 3.8.4 DC Sources-Operating . . . . . . . . . . . . 3.8-24 3.8.5 DC Sources-Shutdown . . . . . . . . . . . . . 3.8-28 3.8.6 Battery Cell Parameters . . . . . . . . . . . 3.8-31 3.8.7 Inverters-Operating . . . . . . . . . . . . . 3.8-35 3.8.8 Inverters-Shutdown . . . 3.8-36 3.8.9 Distribution Systems-Operating 3.8-38 3.8.10 Distribution Systems-Shutdown . . . . . . . . 3.8-41 3.9 REFUELING OPERATIONS . . . . . . . . . . 3.9-1 3.9.1 Refueling Equipment Interlocks . . . . 3.9-1 3.9.2 Refuel Position One-Rod-Out Interlock . ... 3.9-2 3.9.3 Control Rod Position . . 3.9-4 3.9.4 Control Rod Position Indication . . . . . . . 3.9-5 3.9.5 Control Rod OPERABILITY-Refueling . . . . . . 3.9-7 3.9.6 Reactor Pressure Vessel (RPV) Water Level- Irradiated Fuel . . . . . . . . . . 3.9-8 3.9.7 Reactor Pressure Vessel (RPV) Water Level -New Fuel or Control Rods . . . . . 3.9-9 3.9.8 Residual Heat Removal (RHR)-High Water Level 3.9-10 3.9.9 Residual Heat Removal (RHR)-Low Water Level 3.9-12 (continued)

RIVER BEND ii i Revision No. 0

TABLE OF CONTENTS 3.10 SPECIAL OPERATIONS ............... . 3.10-1 3.10.1 Inservice Leak and Hydrostatic Testing Operation . 3.10-1 3.10.2 Reactor Mode Switch Interlock Testing . . . . . . . . . 3.10-4 3.10.3 Single Control Rod Withdrawal-Hot Shutdown . . . . . . 3.10-6 3.10.4 Single Control Rod Withdrawal-Cold Shutdown . . . . . . 3.10-9 3.10.5 Single Control Rod Drive (CRD)

Removal -Refueling . . . . . . . . . . . . . . . . . 3.10-13 3.10.6 Multiple Control Rod Withdrawal-Refueling . . . . . . . 3.10-16 3.10.7 Control Rod Testing-Operating . . . . . . . . . . . . . 3.10-18 3.10.8 SHUTDOWN MARGIN (SDM) Test-Refueling . . . . . . . . . 3.10-19 4.0 DESIGN FEATURES . . . . . . . . . . . . . . . . 4.0-1 4.1 Site Location . . . . . . . . . . . . . . . 4.0-1 4.2 Reactor Core ................ 4.0-1 4.3 Fuel Storage ................ 4.0-1 5.0 ADMINISTRATIVE CONTROLS . . . . . . . . . . . . 5.0-1 5.1 Responsibility . . . . . . . . . . . . . . . 5.0-1 5.2 Organization . . . . . . . . . . . . . . . 5.0-2 5.3 Unit Staff Qualifications . . . . . . . . . 5.0-5 5.4 Procedures . . . 5.0-6 5.5 Programs and Manuals . . . . . . . . . . . . 5.0-7 5.6 Reporting Requirements . . . . . . . . . . . 5.0-17 5.7 High Radiation Area . . . . . . . . . . . . 5.0-20 (continued)

RIVER BEND iv Revision No. 0

Definitions 1.1 1.0 USE AND APPLICATION 1.1 Definitions

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

The defined terms of this section appear in capitalized type and are applicable throughout these Technical Specifications and Bases.

Term Definition ACTIONS ACTIONS shall be that part of a Specification that prescribes Required Actions to be taken under designated Conditions within specified Completion Times.

AVERAGE PLANAR LINEAR The APLHGR shall be applicable to a specific HEAT GENERATION RATE planar height and is equal to the sum of the (APLHGR) LHGRs for all the fuel rods in the specified bundle at the specified height divided by the number of fuel rods in the fuel bundle.

CHANNEL CALIBRATION A CHANNEL CALIBRATION shall be the adjustment, as necessary, of the channel output such that it responds within the necessary range and accuracy to known values of the parameter that the channel monitors. The CHANNEL CALIBRATION shall encompass the entire channel, including the required sensor, alarm, display, and trip functions, and shall include the CHANNEL FUNCTIONAL TEST. Calibration of instrument channels with resistance temperature detector (RTD) or thermocouple sensors may consist of an inplace qualitative assessment of sensor behavior and normal calibration of the remaining adjustable devices in the channel. The CHANNEL CALIBRATION may be performed by means of any series of sequential, overlapping, or total channel steps so that the entire channel is calibrated.

CHANNEL CHECK A CHANNEL CHECK shall be the qualitative assessment, by observation, of channel behavior during operation. This determination shall include, where possible, comparison of the channel indication and status to other indications or status derived from independent instrument channels measuring the same parameter.

(continued)

RIVER BEND 1 .0-1 Amendment No. 81

Definitions 1.1 1.1 Definitions (continued)

CHANNEL FUNCTIONAL TEST A CHANNEL FUNCTIONAL TEST shall be the injection of a simulated or actual signal into the channel as close to the sensor as practicable to verify OPERABILITY, including required alarm, interlock, display, and trip functions, and channel failure trips. The CHANNEL FUNCTIONAL TEST may be performed by means of any series of sequential, overlapping, or total channel steps so that the entire channel is tested.

CORE ALTERATION CORE ALTERATION shall be the movement of any fuel, sources, or reactivity control components within the reactor vessel with the vessel head removed and fuel in the vessel.

The following exceptions are not considered to be CORE ALTERATIONS:

a. Movement of source range monitors, local power range monitors, intermediate range monitors, traversing incore probes, or special movable detectors (including undervessel replacement); and

b. Control rod movement provided there are no fuel assemblies in the associated core cell.

Suspension of CORE ALTERATIONS shall not preclude completion of movement of a component to a safe position.

CORE OPERATING LIMITS The COLR is the unit specific document that provides cycle REPORT (COLR) specific parameter limits for the current reload cycle. These cycle specific limits shall be determined for each reload cycle in accordance with Specification 5.6.5. Plant operation within these limits is addressed in individual Specifications.

DOSE EQUIVALENT 1-131 DOSE EQUIVALENT 1-131 shall be that concentration of 1-131 (microcuries/gram) that alone would produce the same thyroid dose as the quantity and isotopic mixture of 1-131, 1-132,1-133,1-134, and 1-135 actually present. The thyroid dose conversion factors used for this calculation shall be those listed in Federal Guidance Report (FGR) 11, "Limiting Values of Radionuclide Intake and Air Concentration and Dose Conversion Factors for Inhalation, Submersion, and Ingestion," 1989.

(continued)

RIVER BEND 1.0-2 Amendment No. 04, 132

.

Definitions 1.1 1.1 Definitions (continued)

EMERGENCY CORE COOLING The ECCS RESPONSE TIME shall be that time interval SYSTEM (ECCS) RESPONSE from when the monitored parameter exceeds its ECCS TIME initiation setpoint at the channel sensor until the ECCS equipment is capable of performing its safety function (i.e., the valves travel to their required positions, pump discharge pressures reach their required values, etc.). Times shall include diesel generator starting and sequence loading delays, where applicable. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.

END OF CYCLE The EOC-RPT SYSTEM RESPONSE TIME shall be that RECIRCULATION PUMP TRIP time interval from initial movement of the (EOC-RPT) SYSTEM RESPONSE associated turbine stop valve or the turbine TIME control valve to complete suppression of the electric arc between the fully open contacts of the recirculation pump circuit breaker. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.

ISOLATION SYSTEM The ISOLATION SYSTEM RESPONSE TIME shall be that RESPONSE TIME time interval from when the monitored parameter exceeds its isolation initiation setpoint at the channel sensor until the isolation valves travel to their required positions. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.

I (continued)

RIVER BEND 1.0-3 Amendment No. 8-,84 DEC 9 1995

Definitions 1.1 1.1 Definitions (continued)

LEAKAGE LEAKAGE shall be:

a. Identified LEAKAGE

1. LEAKAGE into the drywell such as that from pump seals or valve packing, that is captured and conducted to a sump or collecting tank; or

2. LEAKAGE into the drywell atmosphere from sources that are both specifically located and known either not to interfere with the operation of leakage detection systems or not to be pressure boundary LEAKAGE;

b. Unidentified LEAKAGE All LEAKAGE into the drywell that is not identified LEAKAGE;

c. Total LEAKAGE Sum of the identified and unidentified LEAKAGE;

d. Pressure Boundary LEAKAGE LEAKAGE through a nonisolable fault in a Reactor Coolant System (RCS) component body, pipe wall, or vessel wall.

LINEAR HEAT GENERATION The LHGR shall be the heat generation rate per RATE (LHGR) unit length of fuel rod. It is the integral of the heat flux over the heat transfer area associated with the unit length.

LOGIC SYSTEM FUNCTIONAL A LOGIC SYSTEM FUNCTIONAL TEST shall be a test TEST of all required logic components (i.e., all required relays and contacts, trip units, solid state logic elements, etc.) of a logic circuit, from as close to the sensor as practicable up to, but not including, the actuated device, to verify OPERABILITY. The LOGIC SYSTEM FUNCTIONAL TEST may be performed by means of any series of sequential, overlapping, or total system steps so that the entire logic system is tested.

(continued)

RIVER BEND 1.0-4 Amendment No. 81

Definitions 1.1 1.1 Definitions (continued)

MAXIMUM FRACTION The MFLPD shall be the largest value of the fraction of OF LIMITING limiting power density in the core. The fraction of limiting POWER DENSITY (MFLPD) power density shall be the LHGR existing at a given location divided by the specified LHGR limit for that bundle type.

MINIMUM CRITICAL POWER The MCPR shall be the smallest critical power ratio (CPR)

RATIO (MCPR) that exists in the core for each class of fuel. The CPR is that power in the assembly that is calculated by application of the appropriate correlation(s) to cause some point in the assembly to experience boiling transition, divided by the actual assembly operating power.

MODE A MODE shall correspond to any one inclusive combination of mode switch position, average reactor coolant temperature, and reactor vessel head closure bolt tensioning specified in Table 1.1-1 with fuel in the reactor vessel.

OPERABLE - OPERABILITY A system, subsystem, division, component, or device shall be OPERABLE or have OPERABILITY when it is capable of performing its specified safety function(s) and when all necessary attendant instrumentation, controls, normal or emergency electrical power, cooling and seal water, lubrication, and other auxiliary equipment that are required for the system, subsystem, division, component, or device to perform its specified safety function(s) are also capable of performing their related support function(s).

RATED THERMAL POWER RTP shall be a total reactor core heat transfer rate to the (RTP) reactor coolant of 3091 MWt. I REACTOR PROTECTION The RPS RESPONSE TIME shall be that time interval from SYSTEM (RPS) RESPONSE when the monitored parameter exceeds its RPS trip setpoint TIME at the channel sensor until de-energization of the scram pilot valve solenoids. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.

(continued)

RIVER BEND 1.0-5 Amendment No. 84, 444, 129 JAN 8 p 2003

Definitions 1.1 1.1 Definitions (continued)

SHUTDOWN MARGIN (SDM) *SDM shall be the amount of reactivity by which the reactor is subcritical or would be subcritical throughout the operating cycle assuming that:

a. The reactor is xenon free;

b. The moderator temperature is~ 68oF; corresponding to the most reactive state; and *

c. All control rods are fully inserted except for the single control rod of highest reactivity worth, which is assumed to be fully withdrawn. With control rods not capable of being fully inserted, the reactivity worth of these control rods must be accounted for in the determination of SDM.

STAGGERED TEST BASIS A STAGGERED TEST BASIS shall consist of the testing of one of the systems, subsystems, channels, or other designated components during the interval specified by the Surveillance Frequency, so that all systems, subsystems, channels, or other designated components are tested during n Surveillance Frequency intervals, where n is the total number of systems, subsystems, channels, or other designated components in the associated function.

THERMAL POWER THERMAL POWER shall be the total reactor core heat transfer rate to the reactor coolant.

TURBINE BYPASS SYSTEM The TURBINE BYPASS SYSTEM RESPONSE TIME RESPONSE TIME consists of two components:

a. The time from initial movement of the main turbine stop valve or control valve until 80% of the turbine bypass capacity is established; and

b. The time from initial movement of the main turbine stop valve or control valve until initial movement of the turbine bypass valve.

The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.

RIVER BEND 1.0-6 Amendment No. 8-+, 180

Definitions 1.1 Table 1.1-1 (page 1 of 1)

MODES REACTOR MODE AVERAGE REACTOR MODE TITLE SWITCH POSITION COOLANT TEMPERATURE (OF) 1 Power Operation Run NA 2 Startup Refuel(a) or Startup/Hot NA Standby 3 Hot Shutdown(a) Shutdown > 200 4 Cold Shutdown(a) Shutdown 5 200 5 Refueling(b) Shutdown or Refuel NA (a) All reactor vessel head closure bolts fully tensioned.

(b) One or more reactor vessel head closure bolts less than fully tensioned.

RIVER BEND 1.0-7 Amendment No. 81

Logical Connectors 1.2 1.0 USE AND APPLICATION 1.2 Logical Connectors PURPOSE The purpose of this section is to explain the meaning of logical connectors.

Logical connectors are used in Technical Specifications (TS) to discriminate between, and yet connect, discrete Conditions, Required Actions, Completion Times, Surveillances, and Frequencies. The only logical connectors that appear in TS are AND and OR. The physical arrangement of these connectors constitutes logical conventions with specific meanings.

BACKGROUND Several levels of logic may be used to state Required Actions. These levels are identified by the placement (or nesting) of the logical connectors and by the number assigned to each Required Action. The first level of logic is identified by the first digit of the number assigned to a Required Action and the placement of the logical connector in the first level of nesting (i.e., left justified with the number of the Required Action). The successive levels of logic are identified by additional digits of the Required Action number and by successive indentions of the logical connectors.

When logical connectors are used to state a Condition, Completion Time, Surveillance, or Frequency, only the first level of logic is used, and the logical connector is left justified with the statement of the Condition, Completion Time, Surveillance, or Frequency.

EXAMPLES The following examples illustrate the use of logical connectors.

(continued)

RIVER BEND 1.0-8 Amendment No. 81

Logical Connectors 1.2 1.2 Logical Connectors EXAMPLES EXAMPLE 1.2-1 (continued)

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. LCO not met. A.1 Verify . . .

AND A.2 Restore . . .

In this example, the logical connector AND is used to indicate that, when in Condition A, both Required Actions A.] and A.2 must be completed.

(continued)

RIVER BEND 1 .0-9 Amendment No. 81

Logical Connectors 1.2 1.2 Logical Connectors EXAMPLES EXAMPLE 1.2-2 (continued)

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. LCO not met. A.1 Trip . . .

OR A.2.1 Verify . . .

AND A.2.2.1 Reduce . . .

OR A.2.2.2 Perform . . .

OR A.3 Align . . .

This example represents a more complicated use of logical connectors. Required Actions A.1, A.2, and A.3 are alternative choices, only one of which must be performed as indicated by the use of the logical connector OR and the left justified placement. Any one of these three Actions may be chosen. If A.2 is chosen, then both A.2.1 and A.2.2 must be performed as indicated by the logical connector AND.

Required Action A.2.2 is met by performing A.2.2.1 or A.2.2.2. The indented position of the logical connector OR indicates that A.2.2.1 and A.2.2.2 are alternative choices, only one of which must be performed.

RIVER BEND 1 .0-10 Amendment No. 81

Completion Times 1.3 1.0 USE AND APPLICATION 1.3 Completion Times PURPOSE The purpose of this section is to establish the Completion Time convention and to provide guidance for its use.

BACKGROUND Limiting Conditions for Operation (LCOs) specify minimum requirements for ensuring safe operation of the unit. The ACTIONS associated with an LCO state Conditions that typically describe the ways in which the requirements of the LCO can fail to be met. Specified with each stated Condition are Required Action(s) and Completion Time(s).

DESCRIPTION The Completion Time is the amount of time allowed for completing a Required Action. It is referenced to the time of discovery of a situation (e.g., inoperable equipment or variable not within limits) that requires entering an ACTIONS Condition unless otherwise specified, providing the unit is in a MODE or specified condition stated in the Applicability of the LCO. Required Actions must be completed prior to the expiration of the specified Completion Time. An ACTIONS Condition remains in effect and the Required Actions apply until the Condition no longer exists or the unit is not within the LCO Applicability.

If situations are discovered that require entry into more than one Condition at a time within a single LCO (multiple Conditions), the Required Actions for each Condition must be performed within the associated Completion Time. When in multiple Conditions, separate Completion Times are tracked for each Condition starting from the time of discovery of the situation that required entry into the Condition.

Once a Condition has been entered, subsequent divisions, subsystems, components, or variables expressed in the Condition, discovered to be inoperable or not within limits, will not result in separate entry into the Condition unless specifically stated. The Required Actions of the Condition continue to apply to each additional failure, with Completion Times based on initial entry into the Condition.

(continued)

RIVER BEND 1 .0-11 Amendment No. 81

Completion Times 1.3 1.3 Completion Times DESCRIPTION However, when a subsequent division, subsystem, component, (continued) or variable expressed in the Condition is discovered to be inoperable or not within limits, the Completion Time(s) may be extended. To apply this Completion Time extension, two criteria must first be met. The subsequent inoperability:

a. Must exist concurrent with the first inoperability; and

b. Must remain inoperable or not within limits after the first inoperability is resolved.

The total Completion Time allowed for completing a Required Action to address the subsequent inoperability shall be limited to the more restrictive of either:

a. The stated Completion Time, as measured from the initial entry into the Condition, plus an additional 24 hours1 days 0.143 weeks 0.0329 months ; or

b. The stated Completion Time as measured from discovery of the subsequent inoperability.

The above Completion Time extension does not apply to those Specifications that have exceptions that allow completely separate re-entry into the Condition (for each division, subsystem, component, or variable expressed in the Condition) and separate tracking of Completion Times based on this re-entry. These exceptions are stated in individual Specifications.

The above Completion Time extension does not apply to a Completion Time with a modified "time zero." This modified "time zero" may be expressed as a repetitive time (i.e.,

"once per 8 hours0.333 days 0.0476 weeks 0.011 months ," where the Completion Time is referenced from a previous completion of the Required Action versus the time of Condition entry) or as a time modified by the phrase "from discovery . . ." Example 1.3-3 illustrates one use of this type of Completion Time. The 10 day Completion Time specified for Conditions A and B in Example 1.3-3 may not be extended.

(continued)

RIVER BEND 1.0-12 Amendment No. 81

Completion Times 1.3 1.3 Completion Times (continued)

EXAMPLES The following examples illustrate the use of Completion Times with different types of Conditions and changing Conditions.

EXAMPLE 1.3-1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. Required B.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months Action and associated AND Completion Time not B.2 Be in MODE 4. 36 hours1.5 days 0.214 weeks 0.0493 months met.

Condition B has two Required Actions. Each Required Action has its own separate Completion Time. Each Completion Time is referenced to the time that Condition B is entered.

The Required Actions of Condition B are to be in MODE 3 within 12 hours0.5 days 0.0714 weeks 0.0164 months AND in MODE 4 within 36 hours1.5 days 0.214 weeks 0.0493 months . A total of 12 hours0.5 days 0.0714 weeks 0.0164 months is allowed for reaching MODE 3 and a total of 36 hours1.5 days 0.214 weeks 0.0493 months (not 48 hours2 days 0.286 weeks 0.0658 months ) is allowed for reaching MODE 4 from the time that Condition B was entered. If MODE 3 is reached within 6 hours0.25 days 0.0357 weeks 0.00822 months , the time allowed for reaching MODE 4 is the next 30 hours1.25 days 0.179 weeks 0.0411 months because the total time allowed for. reaching MODE 4 is 36 hours1.5 days 0.214 weeks 0.0493 months .

If Condition B is entered while in MODE 3, the time allowed for reaching MODE 4 is the next 36 hours1.5 days 0.214 weeks 0.0493 months .

(continued)

RIVER BEND 1.0-13 Amendment No. 81

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-2 (continued)

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One pump A.1 Restore pump to 7 days inoperable. OPERABLE status.

B. Required B.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months Action and associated AND Completion Time not B.2 Be in MODE 4. 36 hours1.5 days 0.214 weeks 0.0493 months met.

When a pump is declared inoperable, Condition A is entered.

If the pump is not restored to OPERABLE status within 7 days, Condition B is also entered and the Completion Time clocks for Required Actions B.1 and B.2 start. If the inoperable pump is restored to OPERABLE status after Condition B is entered, Conditions A and B are exited, and therefore, the Required Actions of Condition B may be terminated.

When a second pump is declared inoperable while the first pump is still inoperable, Condition A is not re-entered for the second pump. LCO 3.0.3 is entered, since the ACTIONS do not include a Condition for more than one inoperable pump.

The Completion Time clock for Condition A does not stop after LCO 3.0.3 is entered, but continues to be tracked from the time Condition A was initially entered.

While in LCO 3.0.3, if one of the inoperable pumps is restored to OPERABLE status and the Completion Time for Condition A has not expired, LCO 3.0.3 may be exited and operation continued in accordance with Condition A.

(continued)

RIVER BEND 1.0-14 Amendment No. 81

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-2 (continued)

While in LCO 3.0.3, if-one of the inoperable pumps is restored to OPERABLE status and the Completion Time for Condition A has expired, LCO 3.0.3 may be exited and operation continued in accordance with Condition B. The Completion Time for Condition B is tracked from the time the Condition A Completion Time expired.

On restoring one of the pumps to OPERABLE status, the Condition A Completion Time is not reset, but continues from the time the first pump was declared inoperable. This Completion Time may be extended if the pump restored to OPERABLE status was the first inoperable pump. A 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months extension to the stated 7 days is allowed, provided this does not result in the second pump being inoperable for

> 7 days.

(continued)

RIVER BEND 1.0-15 Amendment No. 81

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-3 (continued)

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One A.1 Restore 7 days Function X Function X subsystem subsystem to AND inoperable. OPERABLE status.

10 days from discovery of failure to meet the LCO B. One B.1 Restore 72 hours3 days 0.429 weeks 0.0986 months Function Y Function Y subsystem subsystem to AND inoperable. OPERABLE status.

10 days from discovery of failure to meet the LCO C. One C.1 Restore 72 hours3 days 0.429 weeks 0.0986 months Function X Function X subsystem subsystem to inoperable. OPERABLE status.

AND OR One C.2 Restore 72 hours3 days 0.429 weeks 0.0986 months Function Y Function Y subsystem subsystem to inoperable. OPERABLE status.

(continued)

RIVER BEND 1.0-16 Amendment No. 81

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-3 (continued)

When one Function X subsystem and one Function Y subsystem are inoperable, Condition A and Condition B are concurrently applicable. The Completion Times for Condition A and Condition B are tracked separately for each subsystem, starting from the time each subsystem was declared inoperable and the Condition was entered. A separate Completion Time is established for Condition C and tracked from the time the second subsystem was declared inoperable (i.e., the time the.situation described in Condition C was discovered).

If Required Action C.2 is completed within the specified Completion Time, Conditions B and C are exited. If the Completion Time for Required Action A.1 has not expired, operation may continue in accordance with Condition A. The remaining Completion Time in Condition A is measured from the time the affected subsystem was declared inoperable (i.e., initial entry into Condition A).

The Completion Times of Conditions A and B are modified by a logical connector, with a separate 10 day Completion Time measured from the time it was discovered the LCO was not met. In this example, without the separate Completion Time, it would be possible to alternate between Conditions A, B, and C in such a manner that operation could continue indefinitely without ever restoring systems to meet the LCO.

The separate Completion Time modified by the phrase "from discovery of failure to meet the LCO" is designed to prevent indefinite continued operation while not meeting the LCO.

This Completion Time allows for an exception to the normal "time zero" for beginning the Completion Time "clock". In this instance, the Completion Time "time zero" is specified as commencing at the time the LCO was initially not met, instead of at the time the associated Condition was entered.

(continued)

RIVER BEND 1.0-17 Amendment No. 81

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-4 (continued)

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 Restore valve(s) 4 hours0.167 days 0.0238 weeks 0.00548 months valves to OPERABLE inoperable. status.

B. Required B.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months Action and associated AND Completion Time not B.2 Be in MODE 4. 36 hours1.5 days 0.214 weeks 0.0493 months met.

A single Completion Time is used for any number of valves inoperable at the same time. The Completion Time associated with Condition A is based on the initial entry into Condition A and is not tracked on a per valve basis.

Declaring subsequent valves inoperable, while Condition A is still in effect, does not trigger the tracking of separate Completion Times.

Once one of the valves has been restored to OPERABLE status, the Condition A Completion Time is not reset, but continues from the time the first valve was declared inoperable. The Completion Time may be extended if the valve restored to OPERABLE status was the first inoperable valve. The Condition A Completion Time may be extended for up to 4 hours0.167 days 0.0238 weeks 0.00548 months provided this does not result in any subsequent valve being inoperable for > 4 hours0.167 days 0.0238 weeks 0.00548 months .

If the Completion Time of 4 hours0.167 days 0.0238 weeks 0.00548 months (plus the extension) expires while one or more valves are still inoperable, Condition B is entered.

(continued)

RIVER BEND 1.0-18 Amendment No. 81

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-5 (continued)

ACTIONS

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

Separate Condition entry is allowed for each inoperable valve.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 Restore valve to 4 hours0.167 days 0.0238 weeks 0.00548 months valves OPERABLE status.

inoperable.

B. Required B.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months Action and associated AND Completion Time not B.2 Be in MODE 4. 36 hours1.5 days 0.214 weeks 0.0493 months met.

The Note above the ACTIONS table is a method of modifying how the Completion Time is tracked. If this method of modifying how the Completion Time is tracked was applicable only to a specific Condition, the Note would appear in that Condition rather than at the top of the ACTIONS Table.

The Note allows Condition A to be entered separately for each inoperable valve, and Completion Times tracked on a per valve basis. When a valve is declared inoperable, Condition A is entered and its Completion Time starts. If subsequent valves are declared inoperable, Condition A is entered for each valve and separate Completion Times start and are tracked for each valve. -

(continued)

RIVER BEND 1 .0-19 Amendment No. 81

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-5 (continued)

If the Completion Time associated with a valve in Condition A expires, Condition B is entered for that valve.

If the Completion Times associated with subsequent valves in Condition A expire, Condition B is entered separately for each valve and separate Completion Times start and are tracked for each valve. If a valve that caused entry into Condition B is restored to OPERABLE status, Condition B is exited for that valve.

Since the Note in this example allows multiple Condition entry and tracking of separate Completion Times, Completion Time extensions do not apply.

EXAMPLE 1.3-6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One channel A.1 Perform Once per inoperable. SR 3.x.x.x. 8 hours0.333 days 0.0476 weeks 0.011 months OR A.2 Reduce THERMAL 8 hours0.333 days 0.0476 weeks 0.011 months POWER to S 50% RTP.

B. Required B.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months Action and associated Completion Time not met.

(continued)

RIVER BEND 1.0-20 Amendment No. 81

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-6 (continued)

Entry into Condition A-offers a choice between Required Action A.1 or A.2. Required Action A.1 has a "once per" Completion Time, which qualifies for the 25% extension, per SR 3.0.2, to each performance after the initial performance.

If Required Action A.1 is followed and the Required Action is not met within the Completion Time (plus the extension allowed by SR 3.0.2), Condition B is entered. If Required Action A.2 is followed and the Completion Time of 8 hours0.333 days 0.0476 weeks 0.011 months is not met, Condition B is entered.

If after entry into Condition B, Required Action A.1 or A.2 is met, Condition B is exited and operation may then continue in Condition A.

(continued)

RIVER BEND 1.0-21 Amendment No. 81

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-7 (continued)

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One A.1 Verify affected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months subsystem subsystem inoperable. isolated. AND Once per 8 hours0.333 days 0.0476 weeks 0.011 months thereafter AND A.2 Restore subsystem 72 hours3 days 0.429 weeks 0.0986 months to OPERABLE status.

B. Required B.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months Action and associated AND Completion Time not B.2 Be in MODE 4. 36 hours1.5 days 0.214 weeks 0.0493 months met.

Required Action A.1 has two Completion Times. The 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Completion Time begins at the time the Condition is entered and each "Once per 8 hours0.333 days 0.0476 weeks 0.011 months thereafter" interval begins upon performance of Required Action A.1.

If after Condition A is entered, Required Action A.1 is not met within either the initial 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or any subsequent 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months interval from the previous performance (plus the extension allowed by SR 3.0.2), Condition B is entered. The Completion Time clock for Condition A does not stop after (continued)

RIVER BEND 1.0-22 Amendment No. 81

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-7 (continued)

Condition B is entered; but continues from the time Condition A was initially entered. If Required Action A.1 is met after Condition B is entered, Condition B is exited and operation may continue in accordance with Condition A, provided the Completion Time for Required Action A.2 has not expired.

IMMEDIATE When "Immediately' is used as a Completion Time, the COMPLETION TIME Required Action should be pursued without delay and in a controlled manner.

RIVER BEND 1.0-23 Amendment No. 81

Frequency 1.4 1.0 USE AND APPLICATION 1.4 Frequency PURPOSE The purpose of this section is to define the proper use and application of Frequency requirements.

DESCRIPTION Each Surveillance Requirement (SR) has a specified Frequency in which the Surveillance must be met in order to meet the associated Limiting Condition for Operation (LCO). An understanding of the correct application of the specified Frequency is necessary for compliance with the SR.

The "specified Frequency" is referred to throughout this section and each of the Specifications of Section 3.0, Surveillance Requirement (SR) Applicability. The "specified Frequency" consists of the requirements of the Frequency column of each SR, as well as certain Notes in the Surveillance column that modify performance requirements.

Sometimes special situations dictate when the requirements of a Surveillance are to be met. They are "otherwise stated" conditions allowed by SR 3.0.1. They may be stated as clarifying Notes in the Surveillance, as part of the Surveillance, or both. Example 1.4-4 discusses these special situations.

Situations where a Surveillance could be required (i.e., its Frequency could expire), but where it is not possible or not desired that it be performed until sometime after the associated LCO is within its Applicability, represent potential SR 3.0.4 conflicts. To avoid these conflicts, the SR (i.e., the Surveillance or the Frequency) is stated such that it is only "required" when it can be and should be performed. With an SR satisfied, SR 3.0.4 imposes no restriction.

The use of "met" or "performed" in these instances conveys specified meanings. A Surveillance is "met" only when the acceptance criteria are satisfied. Known failure of the requirements of a Surveillance, even without a Surveillance specifically being "performed," constitutes a Surveillance not "met." "Performance" refers only to the requirement to specifically determine the ability to meet the acceptance criteria. SR 3.0.4 restrictions would not apply if both the following conditions are satisfied:

(continued)

RIVER BEND 1.0-24 Amendment No. 81

Frequency 1.4 1.4 Frequency DESCRIPTION a. The Surveillance is not required to be performed; and (continued)

b. The Surveillance is not required to be met or, even if required to be met, is not known to'be failed.

EXAMPLES The following examples illustrate the various ways that Frequencies are specified. In these examples, the Applicability of the LCO (LCO not shown) is MODES 1, 2, and 3.

EXAMPLE 1.4-1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY Perform CHANNEL CHECK. 12 hours0.5 days 0.0714 weeks 0.0164 months Example 1.4-1 contains the type of SR most often encountered in the Technical Specifications (TS). The Frequency specifies an interval (12 hours0.5 days 0.0714 weeks 0.0164 months ) during which the associated Surveillance must be performed at least one time.

Performance of the Surveillance initiates the subsequent interval. Although the Frequency is stated as 12 hours0.5 days 0.0714 weeks 0.0164 months , an extension of the time interval to 1.25 times the interval specified in the Frequency is allowed by SR 3.0.2 for operational flexibility. The measurement of this interval continues at all times, even when the SR is not required to be met per SR 3.0.1 (such as when the equipment is inoperable, a variable is outside specified limits, or the unit is outside the Applicability of the LCO). If the interval specified by SR 3.0.2 is exceeded while the unit is in a MODE or other specified condition in the Applicability of the LCO, and the performance of the Surveillance is not otherwise modified (refer to Examples 1.4-3 and 1.4-4), then SR 3.0.3 becomes applicable.

(continued)

RIVER BEND 1.0-25 Amendment No. 81

Frequency 1.4 1.4 Frequency EXAMPLES EXAMPLE 1.4-1 (continued)

If the interval as specified by SR 3.0.2 is exceeded while the unit is not in a MODE or other specified condition in the Applicability of the LCO for which performance of the SR is required, then SR 3.0.4 becomes applicable. The Surveillance must be performed within the Frequency requirements of SR 3.0.2, as modified by SR 3.0.3, prior to entry into the MODE or other specified condition or the LCO is considered not met (in accordance with SR 3.0.1) and LCO 3.0.4 becomes applicable.

EXAMPLE 1.4-2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY Verify flow is within limits. Once within 12 hours0.5 days 0.0714 weeks 0.0164 months after t 23.8% RTP AND 24 hours1 days 0.143 weeks 0.0329 months thereafter Example 1.4-2 has two Frequencies. The first is a one time performance Frequency, and the second is of the type shown in Example 1.4-1. The logical connector "AND" indicates that both Frequency requirements must be met. Each time reactor power is increased from a power level

< 23.8% RTP to t 23.8% RTP, the Surveillance must be performed within 12 hours0.5 days 0.0714 weeks 0.0164 months .

The use of "once" indicates a single performance will satisfy the specified Frequency (assuming no other Frequencies are connected by "AND").

This type of Frequency does not qualify for the extension allowed by SR 3.0.2.

(continued)

RIVER BEND 1.0-26 Amendment No. 81 114, 156

Frequency 1.4 1.4 Frequency EXAMPLES EXAMPLE 1.4-2 (continued)

"Thereafter" indicates future performances must be established per SR 3.0.2, but only after a specified condition is first met (i.e., the "once" performance in this example). If reactor power decreases to

< 23.8% RTP, the measurement of both intervals stops. New intervals start upon reactor power reaching 23.8% RTP.

EXAMPLE 1.4-3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY

NaTE---------------------------

Not required to be performed until 12 hours0.5 days 0.0714 weeks 0.0164 months after

~ 23.8% RTP.

Perform channel adjustment. 7 days The interval continues whether or not the unit operation is < 23.8% RTP between performances.

As the Note modifies the required performance of the Surveillance, it is construed to be part of the "specified Frequency." Should the 7 day interval be exceeded while operation is < 23.8% RTP, this Note allows 12 hours0.5 days 0.0714 weeks 0.0164 months after power reaches ~ 23.8% RTP to perform the Surveillance. The Surveillance is still considered to be within the "specified Frequency."

Therefore, if the Surveillance were not performed within the 7 day interval (plus the extension allowed by SR 3.0.2), but operation was < 23.8% RTP, it would not constitute a failure of the SR or failure to meet the LCO. Also, no violation of SR 3.0.4 occurs when changing MODES, even with the 7 day Frequency not met, provided operation does not exceed 12 hours0.5 days 0.0714 weeks 0.0164 months (plus the extension allowed by SR 3.0.2) with power ~ 23.8% RTP.

(continued)

RIVER BEND 1.0-27 Amendment No. 81.114 161

Frequency 1.4 1.4 Frequency EXAMPLES EXAMPLE 1.4-3 (continued)

Once the unit reaches 23.8% RTP, 12 hours0.5 days 0.0714 weeks 0.0164 months would be allowed for completing the Surveillance. If the Surveillance were not performed within this 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months interval (plus the extension allowed by SR 3.0.2), there would then be a failure to perform a Surveillance within the specified Frequency, and the provisions of SR 3.0.3 would apply.

EXAMPLE 1.4-4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY

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

Only required to be met in MODE 1.

Verify leakage rates are within limits. 24 hours1 days 0.143 weeks 0.0329 months Example 1.4-4 specifies that the requirements of this Surveillance do not have to be met until the unit is in MODE 1. The interval measurement for the Frequency of this Surveillance continues at all times, as described in Example 1.4-1. However, the Note constitutes an "otherwise stated" exception to the Applicability of this Surveillance. Therefore, if the Surveillance were not performed within the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months (plus the extension allowed by SR 3.0.2) interval, but the unit was not in MODE 1, there would be no failure of the SR nor failure to meet the LCO. Therefore, no violation of SR 3.0.4 occurs when changing MODES, even with the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency exceeded, provided the MODE change was not made into MODE 1. Prior to entering MODE 1 (assuming again that the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Frequency were not met), SR 3.0.4 would require satisfying the SR.

RIVER BEND 1.0-28 Amendment No. 81. 114 161

Sls 2.0 2.0 SAFETY LIMITS (Sls) 2.1 Sls 2.1.1 Reactor Core Sls 2.1.1.1 With the reactor steam dome pressure < 685 psig or core flow < 10%

rated core flow:

THERMAL POWER shall be~ 23.8% RTP.

2.1.1.2 With the reactor steam dome pressure ~ 685 psig and core flow

~ 10% rated core flow:

MCPR shall be ~ 1.08 for two recirculation loop operation or~ 1.10 for single recirculation loop operation.

2.1.1.3 Reactor vessel water level shall be greater than the top of active irradiated fuel.

2.1.2 Reactor Coolant System Pressure SL Reactor steam dome pressure shall be~ 1325 psig.

2.2 SL Violations With any SL violation, the following actions shall be completed:

2.2.1 Within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months , notify the NRC Operations Center, in accordance with 10 CFR 50.72.

2.2.2 Within 2 hours0.0833 days 0.0119 weeks 0.00274 months :

2.2.2.1 Restore compliance with all Sls; and 2.2.2.2 Insert all insertable control rods.

2.2.3 Within 24 hours1 days 0.143 weeks 0.0329 months , notify the plant manager and the corporate executive responsible for overall plant nuclear safety.

(continued)

RIVER BEND 2.0-1 Amendment No. ~. 99, W, +Ga, 444' 4-2-2, 182

SLs 2.0 2.0 SLs 2.2 SL Violations (continued) 2.2.4 Within 30 days, a Licensee Event Report (LER) shall be prepared pursuant to 10 CFR 50.73. The LER shall be submitted to the NRC, the plant manager, and the corporate executive responsible for overall plant nuclear safety.

2.2.5 Operation of the unit shall not be resumed until authorized by the NRC.

RIVER BEND 2.0-2 Amendment No. 81

LCO Applicablity 3.0 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY LCO 3.0.1 LCOs shall be met during the MODES or other specified conditions in the Applicability, except as provided in LCO 3.0.2, LCO 3.0.7, and LCO 3.0.9.

LCO 3.0.2 Upon discovery of a failure to meet an LCO, the Required Actions of the associated Conditions shall be met, except as provided in LCO 3.0.5 and LCO 3.0.6.

If the LCO is met or is no longer applicable prior to expiration of the specified Completion Time(s), completion of the Required Action(s) is not required, unless otherwise stated.

LCO 3.0.3 When an LCO is not met and the associated ACTIONS are not met, an associated ACTION is not provided, or if directed by the associated ACTIONS, the unit shall be placed in a MODE or other specified condition in which the LCO is not applicable. Action shall be initiated within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to place the unit, as applicable, in:

a. MODE 2 within 7 hours0.292 days 0.0417 weeks 0.00959 months ;

b. MODE 3 within 13 hours0.542 days 0.0774 weeks 0.0178 months ; and

c. MODE 4 within 37 hours1.542 days 0.22 weeks 0.0507 months .

Exceptions to this Specification are stated in the individual Specifications.

Where corrective measures are completed that permit operation in accordance with the LCO or ACTIONS, completion of the actions required by LCO 3.0.3 is not required.

LCO 3.0.3 is only applicable in MODES 1, 2, and 3.

LCO 3.0.4 When an LCO is not met, entry into a MODE or other specified condition in the Applicability shall only be made:

a. When the associated ACTIONS to be entered permit continued operation in the MODE or other specified condition in the Applicability for an unlimited period of time; (continued)

RIVER BEND 3.0-1 Amendment No. 81,156,173

LCO Applicablity 3.0 3.0 LCO APPLICABILITY LCO 3.0.4 b. After performance of a risk assessment addressing inoperable (continued) systems and components, consideration of the results, determination of the acceptability of entering the MODE or other specified condition in the Applicability, and establishment of risk management actions, if appropriate; exceptions to this Specification are stated in the individual Specifications, or

c. When an allowance is stated in the individual value, parameter, or other Specification.

This Specification shall not prevent changes in MODES or other specified conditions in the Applicability that are required to comply with ACTIONS or that are part of a shutdown of the unit.

LCO 3.0.5 Equipment removed from service or declared inoperable to comply with ACTIONS may be returned to service under administrative control solely to perform testing required to demonstrate its OPERABILITY or the OPERABILITY of other equipment. This is an exception to LCO 3.0.2 for the system returned to service under administrative control to perform the testing required to demonstrate OPERABILITY.

LCO 3.0.6 When a supported system LCO is not met solely due to a support system LCO not being met, the Conditions and Required Actions associated with this supported system are not required to be entered. Only the support system LCO ACTIONS are required to be entered. This is an exception to LCO 3.0.2 for the supported system. In this event, additional evaluations and limitations may be required in accordance with Specification 5.5.10, "Safety Function Determination Program (SFDP)." If a loss of safety function is determined to exist by this program, the appropriate Conditions and Required Actions of the LCO in which the loss of safety function exists are required to be entered.

When a support system's Required Action directs a supported system to be declared inoperable or directs entry into Conditions and Required Actions for a supported system, the applicable Conditions and Required Actions shall be entered in accordance with LCO 3.0.2.

(continued)

RIVER BEND 3.0-2 Amendment No. 81, 156

LCO Applicablity 3.0 3.0 LCO APPLICABILITY (continued)

LCO 3.0.7 Special Operations LCOs in Section 3.10 allow specified Technical Specifications (TS) requirements to be changed to permit performance of special tests and operations. Unless otherwise specified, all other TS requirements remain unchanged. Compliance with Special Operations LCOs is optional. When a Special Operations LCO is desired to be met but is not met, the ACTIONS of the Special Operations LCO shall be met.

When a Special Operations LCO is not desired to be met, entry into a MODE or other specified condition in the Applicability shall only be made in accordance with the other applicable Specifications.

LCO 3.0.8 Not Used LCO 3.0.9 When one or more required barriers are unable to perform their related support function(s), any supported system LCO(s) are not required to be declared not met solely for this reason for up to 30 days provided that at least one train or subsystem of the supported system is OPERABLE and supported by barriers capable of providing their related support function(s), and risk is assessed and managed. This specification may be concurrently applied to more than one train or subsystem of a multiple train or subsystem supported system provided at least one train or subsystem of the supported system is OPERABLE and the barriers supporting each of these trains or subsystems provide their related support function(s) for different categories of initiating events.

For the purposes of this specification, the High Pressure Core Spray system, the Reactor Core Isolation Cooling system, and the Automatic Depressurization System are considered independent subsystems of a single system.

If the required OPERABLE train or subsystem becomes inoperable while this specification is in use, it must be restored to OPERABLE status within 24 hours1 days 0.143 weeks 0.0329 months or the provisions of this specification cannot be applied to the trains or subsystems supported by the barriers that cannot perform their related support function(s).

At the end of the specified period, the required barriers must be able to perform their related support function(s) or the supported system LCO(s) shall be declared not met.

RIVER BEND 3.0-3 Amendment No. 84-, 173

-

SR Applicability 3.0

- 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY SR 3.0.1 SRs shall be met during the MODES or other specified conditions in the Applicability for individual LCOs, unless otherwise stated in the SR.

Failure to meet a Surveillance, whether such failure is experienced during the performance of the Surveillance or between performances of the Surveillance, shall be failure to meet the LCO. Failure to perform a Surveillance within the specified Frequency shall be failure to meet the LCO except as provided in SR 3.0.3. Surveillances do not have to be performed on inoperable equipment or variables outside specified limits.

SR 3.0.2 The specified Frequency for each SR is met if the Surveillance Is performed within 1.25 times the interval specified in the Frequency, as measured from the previous performance or as measured from the time a specified condition of the Frequency is met.

For Frequencies specified as 'once," the above interval extension does not apply.

If a Completion Time requires periodic performance on a 'once per. ..

basis, the above Frequency extension applies to each performance after the initial performance.

Exceptions to this Specification are stated In the individual Specifications.

SR 3.0.3 If it is discovered that a Surveillance was not performed within its specified Frequency, then compliance with the requirement to declare the LCO not met may be delayed, from the time of discovery, up to 24 hours1 days 0.143 weeks 0.0329 months or up to the limit of the specified Frequency, whichever is greater. This delay period is permitted to allow performance of the Surveillance. A risk evaluation shall be performed for any surveillance delayed greater than 24 hours1 days 0.143 weeks 0.0329 months and the risk impact shall be managed.

If the Surveillance is not performed within the delay period, the LCO must immediately be declared not met, and the applicable Condition(s) must be entered.

When the Surveillance is performed within the delay period and the Surveillance is not met, the LCO must immediately be declared not met, and the applicable Condition(s) must be entered.

(continued)

RIVER BEND 3.0-4 Amendment No.84 127 JAN 02 w

SR Applicability 3.0 3.0 SR APPLICABILITY (continued)

SR 3.0.4 Entry into a MODE or other specified condition in the Applicability of an LCO shall only be made when the LCO's Surveillances have been met within their specified Frequency, except as provided by SR 3.0.3. When an LCO is not met due to Surveillances not having been met, entry into a MODE or other specified condition in the Applicability shall only be made in accordance with LCO 3.0.4.

This provision shall not prevent entry into MODES or other specified conditions in the Applicability that are required to comply with ACTIONS or that are part of a shutdown of the unit.

RIVER BEND 3.0-5 Amendment No. 81, 156

SDM 3.1.1 3.1 REACTIVITY CONTROL SYSTEMS 3.1.1 SHUTDOWN MARGIN (SDM)

LCO 3.1.1 SDM shall be:

a. 2 0.38% Ak/k, with the highest worth control rod analytically determined; or

b. 2 0.28% Ak/k, with the highest worth control rod determined by test.

APPLICABILITY: MODES 1, 2, 3, 4, and 5.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. SDM not within limits A.1 Restore SDM to within 6 hours0.25 days 0.0357 weeks 0.00822 months in MODE 1 or 2. limits.

B. Required Action and B.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months associated Completion Time of Condition A not met.

C. SDM not within limits C.1 Initiate action to Immediately in MODE 3. fully insert all insertable control rods.

D. SDM not within limits D.1 Initiate action to Immediately in MODE 4. fully insert all insertable control rods.

AND (continued)

RIVER BEND 3.1-1 Amendment No. 81

-

SDM 3.1.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. (continued) D.2 Initiate action to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months restore primary containment to OPERABLE status.

AND D.3 -------- NOTE---------

Entry and exit is permissible under administrative control.

Initiate action to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months close one door in each primary containment air lock.

E. SDM not within limits E.1 Suspend CORE Immediately in MODE 5. ALTERATIONS except for control -rod insertion and fuel assembly removal.

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

AND E.3 Initiate action to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months restore primary containment to OPERABLE status.

AND (continued)

RIVER BEND 3.1-2 Amendment No. 81

SDM 3.1.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME E. (continued) E.4 --------NOTE---------

Entry and exit is permissible under administrative control.

Initiate action to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months close one door in each primary containment air lock.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.1.1 Verify SDM is: Prior to each in-vessel fuel

a. 2 0.38% Ak/k with the highest worth movement during control rod analytically determined; fuel loading or sequence

b. z 0.28% Ak/k with the highest worth AND control rod determined by test.

Once within 4 hours0.167 days 0.0238 weeks 0.00548 months after criticality following fuel movement within the reactor pressure vessel or control rod replacement RIVER BEND 3.1-3 Amendment No. 81

Reactivity Anomalies 3.1.2 3.1 REACTIVITY CONTROL SYSTEMS 3.1.2 Reactivity Anomalies LCO 3.1.2 The reactivity difference between the monitored core k-eff and the predicted core k-eff shall be within i 1% Ak/k. I APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Core reactivity A.1 Restore core 72 hours3 days 0.429 weeks 0.0986 months difference not within reactivity difference limit. to within limit.

B. Required Action and B.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months associated Completion Time not met.

__ RIVER BEND 3.1-4 Amendment No. 1I,1OO OCT I O 1997

_ _.-

Reactivity Anomalies 3.1.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY t

SR 3.1.2.1 Verify core reactivity difference between Once within the actual and the predicted reactivity is 24 hours1 days 0.143 weeks 0.0329 months after I within +/- 1% ,k/k. reaching equilibrium conditions following startup after fuel movement within the reactor pressure vessel or control rod replacement 1000 MWD/T thereafter during operation in MODE I RIVER BEND 3.1-5 Amendment No. 84,lOO OCT 1 0 1997

Control Rod OPERABILITY 3.1.3 3.1 REACTIVITY CONTROL SYSTEMS 3.1.3 Control Rod OPERABILITY LCO 3.1.3 Each control rod shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS

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

Separate Condition entry is allowed for each control rod.

CONDITION REQUIRED ACTION COMPLETION TIME A. One withdrawn control ------------NOTE-------------

rod stuck. A stuck rod may be bypassed in the Rod Action Control System (RACS) in accordance with SR 3.3.2.1.9 if required to allow continued operation.

A.1 Disarm the associated 2 hours0.0833 days 0.0119 weeks 0.00274 months control rod drive (CRO).

AND (continued)

RIVER BEND 3.1-6 Amendment No. 81

Control Rod OPERABILITY 3.1.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2 Perform SR 3.1.3.3 for 24 hours1 days 0.143 weeks 0.0329 months from each withdrawn OPERABLE discovery of control rod. Condition A concurrent with THERMAL POWER greater than the low power setpoint (LPSP) of the Rod Pattern Control AND System (RPCS)

A.3 Perform SR 3.1.1.1.

72 hours3 days 0.429 weeks 0.0986 months B. Two or more withdrawn B.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months control rods stuck.

C. One or more control rods C.1 ----------NOTE---------

inoperable for reasons Inoperable control rods other than Condition A may be bypassed in or B. RACS in accordance with SR 3.3.2.1.9, if required, to allow insertion of inoperable control rod and continued operation.

Fully insert inoperable 3 hours0.125 days 0.0179 weeks 0.00411 months control rod.

AND (continued)

RIVER BEND 3.1-7 Amendment No. 8-+ 161

Control Rod OPERABILITY 3.1.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. (continued) C.2 Disarm the associated CRD. 4 hours0.167 days 0.0238 weeks 0.00548 months D. --------- NOTE--------- D.1 Restore compliance with 4 hours0.167 days 0.0238 weeks 0.00548 months Not applicable when BPWS.

I THERMAL POWER > 10% RTP.

OR Two or more inoperable D.2 Restore control rod to 4 hours0.167 days 0.0238 weeks 0.00548 months control rods not in OPERABLE status.

compliance with banked position withdrawal sequence (BPWS) and not separated by two or more OPERABLE control rods.

E. Required Action and E.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months associated Completion Time of Condition A. C.

or D not met.

OR Nine or more control rods inoperable.

RIVER BEND 3.1-8 Amendment No. 81-. 118

Control Rod OPERABILITY 3.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.3.1 Determine the position of each control rod. 24 hours1 days 0.143 weeks 0.0329 months SR 3.1.3.2 DELETED SR 3.1.3.3 ---------------------------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.

Insert each withdrawn control rod at least one notch. 31 days SR 3.1.3.4 Verify each control rod scram time from fully In accordance with withdrawn to notch position 13 is s 7 seconds. SR 3.1.4.1, SR 3.1.4.2, SR 3.1.4.3, and SR 3.1.4.4 (continued)

RIVER BEND 3.1-9 Amendment No. 8-+ 161

Control Rod OPERABILITY 3.1.3 SURVEILLANCE REQUIREMENTS (continued)

T SURVEILLANCE FREQUENCY 7

SR 3.1.3.5 Verify each control rod does not go to the Each time the withdrawn overtravel position. control rod is withdrawn to "full out" position AND Prior to declaring control rod OPERABLE after work on control rod or CRD System that could affect coupling RIVER BEND 3.1-10 Amendment No. 81

Control Rod Scram Times 3.1.4 3.1 REACTIVITY CONTROL SYSTEMS 3.1.4 Control Rod Scram Times LCO 3.1.4 a. No more than 10 OPERABLE control rods shall be "slow,"

in accordance with Table 3.1.4-1; and

b. No OPERABLE control rod that is "slow" shall occupy a location adjacent to another OPERABLE control rod that is "slow" or a withdrawn control rod that is stuck.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of the A.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months LCO not met.

RIVER BEND 3.1-11 Amendment No. 81

Control Rod Scram Times 3.1.4 SURVEILLANCE REQUIREMENTS

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

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

SURVEILLANCE FREQUENCY SR 3.1.4.1 Verify each control rod scram time is within the limits Prior to exceeding of Table 3.1.4-1 with reactor steam dome pressure 40% RTP after

950 psig. each reactor shutdown

120 days SR 3.1.4.2 Verify, for a representative sample, each tested 200 days control rod scram time is within the limits of cumulative Table 3.1.4-1 with reactor steam dome pressure operation in

950 psig. MODE 1 SR 3.1.4.3 Verify each affected control rod scram time is within Prior to declaring the limits of Table 3.1.4-1 with any reactor steam control rod dome pressure. OPERABLE after work on control rod or CRD System that could affect scram time (continued)

RIVER BEND 3.1-12 Amendment No. 81 126, 165

Control Rod Scram Times 3.1.4 SURVEILLANCE FREQUENCY SR 3.1.4.4 Verify each affected control rod scram time is within the Prior to exceeding limits of Table 3.1.4-1 with reactor steam dome 40% RTP after fuel pressure ~ 950 psig. movement within the affected core cell Prior to exceeding 40% RTP after work on control rod or CRD System that could affect scram time RIVER BEND 3.1-13 Amendment No. 3t, 165

Control Rod Scram Times 3.1.4 Table 3.1.4-1 Control Rod Scram Times

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

1. OPERABLE control rods with scram times not within the limits of this Table are considered "slow."

2. Enter applicable Conditions and Required Actions of LCO 3.1.3. "Control Rod OPERABILITY," for control rods with scram times > 7 seconds to notch position 13. These control rods are inoperable. in accordance with SR 3.1.3.4, and are not considered "slow."

SCRAM TIMES(a)(b)

(seconds)

REACTOR REACTOR STEAM DOME PRESSURE(c) STEAM DOME PRESSURE(c)

I NOTCH POSITION 950 psig 1059 psig 43 0.30 0.31 29 0.78 0.84 13 1.40 1.53 (a) Maximum scram time from fully withdrawn position. based on de-energization of scram pilot valve solenoids as time zero.

(b) Scram times as a function of reactor steam dome pressure when < 950 psig are within established limits.

(c) For intermediate reactor steam dome pressures. the scram time criteria are determined by linear interpolation.

RIVER BEND 3.1-14 Amendment No. At 114 OCT 06 2000

Control Rod Scram Accumulators 3.1.5 3.1 REACTIVITY CONTROL SYSTEMS 3.1.5 Control Rod Scram Accumulators LCO 3.1.5 Each control rod scram accumulator shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS

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

Separate Condition entry is allowed for each control rod scram accumulator.

CONDITION REQUIRED ACTION COMPLETION TIME A. One control rod scram A.1 -------- NOTE--------

accumulator inoperable Only applicable if with reactor steam the associated dome pressure control rod scram

> 600 psig. time was within the limits of Table 3.1.4-1 during the last scram time Surveillance.

Declare the 8 hours0.333 days 0.0476 weeks 0.011 months associated control rod scram time "slow."

OR A.2 Declare the 8 hours0.333 days 0.0476 weeks 0.011 months associated control rod inoperable.

(continued)

RIVER BEND 3.1-15 Amendment No. 81

-

Control Rod Scram Accumulators 3.1.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Two or more control rod B.1 Restore charging water 20 minutes from scram accumulators header pressure to discovery of inoperable with reactor k 1540 psig. Condition B steam dome pressure concurrent with 2 600 psig. charging water header pressure

< 1540 psig AND B.2.1 -------- NOTE---------

Only applicable if the associated control rod scram time was within the limits of Table 3.1.4-1 during the last scram time Surveillance.

Declare the associated control rod scram time "slow." 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months OR B.2.2 Declare the associated control rod inoperable.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months C. One or more control rod C.1 Verify all control rods Immediately upon scram accumulators associated with inoperable discovery of inoperable with reactor accumulators are fully charging water steam dome pressure inserted. header pressure

< 600 psig. < 1540 psig AND (continued)

RIVER BEND 3.1-16 Amendment No. W- 114 OCT 0 6 2&0

Control Rod Scram Accumulators 3.1.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. (continued) C.2 Declare the associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months control rod inoperable.

D. Required Action and D.1 -------- NOTE---------

associated Completion Not applicable if all Time of Required Action inoperable control rod B.1 or C.1 not met. scram accumulators are associated with fully inserted control rods.

Place the reactor mode Immediately switch in the shutdown position.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.5.1 Verify each control rod scram accumulator 7 days I pressure is Ž 1540 psig.

RIVER BEND 3.1-17 Amendment No. 8i-, 114 OCT 0 6 2000

Control Rod Pattern 3.1.6 3.1 REACTIVITY CONTROL SYSTEMS 3.1.6 Control Rod Pattern LCO 3.1.6 OPERABLE control rods shall comply with the requirements of the banked position withdrawal sequence (BPWS).

i APPLICABILITY: MODES 1 and 2 with THERMAL POWER s 10% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more OPERABLE A.1 --------NOTE---------

control rods not in Affected control rods compliance with BPWS. may be bypassed in Rod Action Control System (RACS) in accordance with SR 3.3.2.1.9.

Move associated control 8 hours0.333 days 0.0476 weeks 0.011 months rod(s) to correct position.

OR A.2 Declare associated control 8 hours0.333 days 0.0476 weeks 0.011 months rod(s) inoperable.

(continued)

RIVER BEND 3.1-18 Amendment No. 81-. 118

Control Rod Pattern 3.1.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Nine or more OPERABLE B.1 -------- NOTE---------

control rods not in Affected control rods compliance with BPWS. may be bypassed in RACS in accordance with SR 3.3.2.1.9 for insertion only.

Suspend withdrawal of Immediately control rods.

AND B.2 Place the reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months mode switch in the shutdown position.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.6.1 Verify all OPERABLE control rods comply 24 hours1 days 0.143 weeks 0.0329 months with BPWS.

RIVER BEND 3.1-19 Amendment No. 81

SLC System 3.1.7 3.1 REACTIVITY CONTROL SYSTEMS 3.1.7 Standby Liquid Control (SLC) System LCO 3.1.7 Two SLC subsystems shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME I A. (C)(E) < 570. A.1 Restore (C)(E) 2 570. 72 hours3 days 0.429 weeks 0.0986 months AND 10 days from discovery of failure to meet the LCO B. One SLC subsystem B.1 Restore SLC subsystem to 7 days inoperable for reasons OPERABLE status.

other than Condition A. AND 10 days from discovery of failure to meet the LCO C. Two SLC subsystems C.1 Restore one SLC subsystem 8 hours0.333 days 0.0476 weeks 0.011 months inoperable for reasons to OPERABLE status.

other than Condition A.

D. Required Action and 0.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months associated Completion Time not met.

RIVER BEND 3.1-20 Amendment No. 8F-.114 OCT 0 6 2JJD

SLC System 3.1.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.7.1 ------------------- NOTE--------------------

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 24 hours1 days 0.143 weeks 0.0329 months minimum required available solution volume.

SR 3.1.7.2 Verify temperature of sodium pentaborate 24 hours1 days 0.143 weeks 0.0329 months solution is 2 450F.

SR 3.1.7.3 ------------------- NOTE--------------------

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: 31 days I (C)(E) 2 570 SR 3.1.7.4 Verify continuity of explosive charge. 31 days (continued)

RIVER BEND 3.1-21 Amendment No. S-. 114 OCT 0 6 2000

SLC System 3.1.7 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.1.7.5 Verify the available weight of Boron-1 0 is ~ 170 Ibs, 31 days and the percent weight concentration of sodium pentaborate in solution is:::; 9.5% by weight, and determine the minimum required available solution volume. Once within 24 hours1 days 0.143 weeks 0.0329 months after water or boron is added to solution Once within 24 hours1 days 0.143 weeks 0.0329 months after solution temperature is restored to ~ 45°F SR 3.1.7.6 Verify each SLC subsystem manual, power operated, 31 days 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.

SR 3.1.7.7 Verify each pump develops a flow rate ~ 41.2 gpm at In accordance with a discharge pressure ~ 1250 psig. the Inservice Testing Program SR 3.1.7.8 Verify flow through one SLC subsystem from pump 24 months on a into reactor pressure vessel. STAGGERED TEST BASIS (continued)

RIVER BEND 3.1-22 Amendment No. 81 114, 168

SLC System 3.1.7 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.1.7.9 Determine Boron-10 enrichment of the Once within 24 solution. hours after boron is added to the solution RIVER BEND 3.1-23 Amendment No. 81

SDV Vent and Drain Valves 3.1.8 3.1 REACTIVITY CONTROL SYSTEMS 3.1.8 Scram Discharge Volume (SDV) Vent and Drain Valves LCO 3.1.8 Each SDV vent and drain valve shall be OPERABLE.

APPLICABILITY: MODES I and 2.

ACTIONS

1. Separate Condition entry is allowed for each SDV vent and drain line.

2. An isolated line may be unisolated under administrative control to allow draining and venting of the SDV.

-__---- -_ ----- ________ __

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more SDV vent or A.1 Isolate the associated 7 days drain lines with one valve inoperable.

line. I B. One or more SDV vent or B.1 Isolate the associated 8 hours0.333 days 0.0476 weeks 0.011 months drain lines with both valves line.

inoperable.

C. Required Action and C.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months associated Completion Time-not met.

RIVER BEND 3.1-24 Amendment No. 140

SDV Vent and Drain Valves 3.1.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.8.1 ---------------------------NOTE--------------------------------

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. 31 days SR 3.1.8.2 Cycle each SDV vent and drain valve to the fully 92 days closed and fUlly open position.

SR 3.1.8.3 Verify each SDV vent and drain valve: 24 months

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.

RIVER BEND 3.1-25 Amendment No.--3:1, 168

- -

APLHGR 3.2.1 3.2 POWER DISTRIBUTION LIMITS 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.

I APPLICABILITY: THERMAL POWER 2 23.8% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Any APLHGR not within A.1 Restore APLHGR(s) to within 2 hours0.0833 days 0.0119 weeks 0.00274 months limits. limits.

B. Required Action and B.1 Reduce THERMAL POWER to 4 hours0.167 days 0.0238 weeks 0.00548 months

<JI associated Completion < 23.8% RTP.

Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.1.1 Verify all APLHGRs are less than or equal to Once within the limits specified in the COLR. 12 hours0.5 days 0.0714 weeks 0.0164 months after 2 23.8% RTP AND 24 hours1 days 0.143 weeks 0.0329 months thereafter RIVER BEND ( 3.2-1 Amendment No. S-. 114 OCT 0 6 2000

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

LCO 3.2.2 All MCPRs sh'all be greater-than or equal to the MCPR operating limits specified in the COLR.

I APPLICABILITY: THERMAL POWER 2 23.8% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Any MCPR not within A.1 Restore MCPR(s) to within 2 hours0.0833 days 0.0119 weeks 0.00274 months limits. limits.

B. Required Action and B.1 Reduce THERMAL POWER to 4 hours0.167 days 0.0238 weeks 0.00548 months associated Completion < 23.8% RTP.

Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.2.1 Verify all MCPRs are greater than or equal to Once within the limits specified in the COLR. 12 hours0.5 days 0.0714 weeks 0.0164 months after

. 23.8% RTP AND 24 hours1 days 0.143 weeks 0.0329 months thereafter RIVER BEND 3.2-2 Amendment No. 8g-. 114 OCT 0 6 2O0

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

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

I APPLICABILITY: THERMAL POWER 2 23.8% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Any LHGR not within A.1 Restore LHGR(s) to within 2 hours0.0833 days 0.0119 weeks 0.00274 months limits. limits.

B. Required Action and B.1 Reduce THERMAL POWER to 4 hours0.167 days 0.0238 weeks 0.00548 months I associated Completion < 23.8% RTP.

Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.3.1 Verify all LHGRs are less than or equal to the Once within limits specified in the COLR. 12 hours0.5 days 0.0714 weeks 0.0164 months after 2 23.8% RTP AND 24 hours1 days 0.143 weeks 0.0329 months thereafter RIVER BEND 3.2-3 Amendment No. 8j-, 114 OCT 0 6 2000

FCBB 3.2.4 3.2 POWER DISTRIBUTION LIMITS 3.2.4 Fraction of Core Boiling Boundary (FCBB)

LCO 3.2.4 The FCBB shall be < 1.0.

APPLICABILITY: THERMAL POWER and core flow in the Restricted Region as specified in the COLR.

MODE 1 when RPS Function 2.b. APRM Flow Biased Simulated Thermal Power-High. Allowable Value is "Setup" as specified in the COLR.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. FCBB not within limit A. Restore FCBB to within 2 hours0.0833 days 0.0119 weeks 0.00274 months for reasons other than limit.

an unexpected loss of feedwater heating or unexpected reduction in core flow.

(continued)

RIVER BEND 3.2-4 Amendment No. 106 MAY o 5 1999 LQk mnA&t_ olea en&~ euxac3l

FCBB 3.2.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Initiate action to exit Immediately associated Completion the Restricted Region.

Time of Condition A not met.

AND OR

NOTE-------- B.2 Initiate action to return Required Action B.1 APRM Flow Biased Simulated Immediately and Required Action Thermal Power-High following exit B.2 shall be completed Allowable Value to "non- of Restricted if this Condition is Setup" value. Region entered due to an unexpected loss of feedwater heating or unexpected reduction in core flow.

FCBB not within limit due to an unexpected loss of feedwater heating or unexpected reduction in core flow.

RIVER BEND 3.2-5 Amendment No.106 MAY o 5 1399

_shQQ "Qaf jHe Rtgta

FCBB 3.2.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.4.1 ------------------NOTE ------------------

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. 124 hours5.167 days 0.738 weeks 0.17 months AND Once within 15 minutes following unexpected transient RIVER BEND

3.2-6 Amendment No. 106

,~AY 0 5 fits

-sx krItUN& c did% ugljl ou;64L 9

RPS Instrumentation 3.3.1.1 3.3 INSTRUMENTATION 3.3.1.1 Reactor Protection System (RPS) Instrumentation LCO 3.3.1.1 The RPS instrumentation for each Function in Table 3.3.1.1-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.1.1-1.

ACTIONS

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

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Place channel in 12 hours0.5 days 0.0714 weeks 0.0164 months channels inoperable. trip.

OR A.2 Place associated trip 12 hours0.5 days 0.0714 weeks 0.0164 months system in trip.

B. One or more Functions B.1 Place channel in one 6 hours0.25 days 0.0357 weeks 0.00822 months with one or more trip system in trip.

required channels inoperable in both OR trip systems.

B.2 Place one trip system 6 hours0.25 days 0.0357 weeks 0.00822 months in trip.

C. One or more Functions C.1 Restore RPS trip 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months with RPS trip capability.

capability not maintained.

(continued)

RIVER BEND 3 .3-1 Amendment No. 81

RPS Instrumentation 3.3.1.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Enter the Condition Immediately associated Completion referenced in Time of Condition A. B. Table 3.3.1.1-1 for the or C not met. channel.

E. As required by Required .E.1 Reduce THERMAL POWER to 4 hours0.167 days 0.0238 weeks 0.00548 months Action D.1 and < 40% RTP.

referenced in Table 3.3.1.1-1.

F. As required by Required F.1 Reduce THERMAL POWER to 4 hours0.167 days 0.0238 weeks 0.00548 months I Action D.1 and < 23.8% RTP.

referenced in Table 3.3.1.1-1.

G. As required by Required G.1 Be in MODE 2. 6 hours0.25 days 0.0357 weeks 0.00822 months Action D.1 and referenced in Table 3.3.1.1-1.

H. As required by Required H.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months Action D.1 and referenced in Table 3.3.1.1-1.

I. As required by Required I.1 Initiate action to fully Immediately Action D.1 and insert all insertable referenced in control rods in core cells Table 3.3.1.1-1. containing one or more fuel assemblies.

RIVER BEND 3.3-2 Amendment No. 8-. 114 OCT 0 6 2000

RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS

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

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 hours0.25 days 0.0357 weeks 0.00822 months provided the associated Function maintains RPS trip capability.

SURVEILLANCE FREQUENCY SR 3.3.1.1.1 Perform CHANNEL CHECK. 12 hours0.5 days 0.0714 weeks 0.0164 months SR 3.3.1.1.2 ------- 7-----------NOTE-------------------

Not required to be performed until 12 hours after THERMAL POWER 2 23.8% RTP.

I. Verify the absolute difference between the 7 days average power range monitor (APRM) channels and the calculated power s 2% RTP' )

SR 3.3.1.1.3 Adjust the flow control trip reference card Once within to conform to reactor flowb'. 7 days after reaching equilibrium conditions following refueling outage.

(a) For a period of 30 days beginning with uprate COLR 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 COLR 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 COLR.

(continued)

RIVER BEND 3.3-3 Amendment No. 8-. 1-0. I6- 114 OCT 06 2W30

RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.1.4 ------------------NOTE-------------------

Not required to be performed when entering MODE 2 from MODE 1 until 12 hours0.5 days 0.0714 weeks 0.0164 months after entering MODE 2.

Perform CHANNEL FUNCTIONAL TEST. 7 days SR 3.3.1.1.5 Perform CHANNEL FUNCTIONAL TEST. 7 days SR 3.3.1.1.6 Verify the source range monitor (SRM) and Prior to intermediate range monitor (IRM) channels withdrawing SRMs overlap. from the fully inserted position SR 3.3.1.1.7 -------------------NOTE-------------------

Only required to be met during entry into MODE 2 from MODE 1.

Verify the IRM and APRM channels overlap. 7 days SR 3.3.1.1.8 Calibrate the local power range monitors. 2000 !4WD/T average core exposure SR 3.3.1.1.9 Perform CHANNEL FUNCTIONAL TEST. 92 days (continued)

RIVER BEND 3.3-4 Amendment No. 8&-. &. 1G&.}O7 114 OCT 0 6 2000

RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.1.10 Calibrate the trip units. 92 days SR 3.3.1.1.11 -------------------------------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 hours0.5 days 0.0714 weeks 0.0164 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. 184 days SR 3.3.1.1.12 Perform CHANNEL FUNCTIONAL TEST. 24 months SR 3.3.1.1.13 ---------------------------------NOTES-----------------------

1. Neutron detectors are excluded.

2. For IRMs, not required to be performed when entering MODE 2 from MODE 1 until 12 hours0.5 days 0.0714 weeks 0.0164 months after entering MODE 2.

Perform CHANNEL CALIBRATION. 24 months SR 3.3.1.1.14 Verify the APRM Flow Biased Simulated Thermal 24 months Power-High time constant is within the limits specified in the COLR.

(continued)

RIVER BEND 3.3-5 Amendment No. 81 106 114, 168

RPS Instrumentation 3.3.1.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.1.15 Perform LOGIC SYSTEM FUNCTIONAL TEST. 24 months SR 3.3.1.1.16 Verify Turbine Stop Valve Closure and Turbine 24 months Control Valve Fast Closure Trip Oil Pressure-Low Functions are not bypassed when THERMAL POWER is ::?: 40% RTP.

SR 3.3.1.1.17 Calibrate the flow reference transmitters. 24 months SR 3.3.1.1.18 ---------------------------NOTES-----------------------------

1. Neutron detectors are excluded.

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

3. For Function 6, "n" equals 4 channels for the purpose of determining the STAGGERED TEST BASIS Frequency.

Verify the RPS RESPONSE TIME is within limits. 24 months on a STAGGERED TEST BASIS RIVER BEND 3.3-6 Amendment No. 81 106114,168

RPS Instrumentation 3.3.1.1 Table 3.3.1.1-1 (page 1 of 3)

Reactor Protection System Instrumentation CONDITIONS APPLICABLE REQUIRED REFERENCED MODES OR OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D.1 REQUIREMENTS VALUE

1. Intermediate Range Monitors

a. Neutron Flux - High 2 3 H SR 3.3.1.1.1 s 122/125 SR 3.3.1.1.4 divisions SR 3.3.1.1.6 of full SR 3.3.1.1.7 scale SR 3.3.1.1.13 SR 3.3.1.1.15 5(a) 3 1 SR 3.3.1.1.1 s 122/125 SR 3.3.1.1.5 divisions SR 3.3.1.1.13 of full SR 3.3.1.1.15 scale

b. Inop 2 3 H SR 3.3.1.1.4 NA SR 3.3.1.1.15 5(a) 3 1 SR 3.3.1.1.5 NA SR 3.3.1.1.15

2. Average Power Range Monitors

a. Neutron Flux - High, 2 3 H SR 3.3.1.1.1 s 20% RTP Setdown SR 3.3.1.1.4 SR 3.3.1.1.7 SR 3.3.1.1.8 SR 3.3.1.1.11 SR 3.3.1.1.15 I b. Flow Biased Simulated 1 3 G SR 3.3.1.1.1 (b)(c)

Thermal Power - High SR 3.3.1.1.2 SR 3.3.1.1.3 SR 3.3.1.1.8 SR 3.3.1.1.9 SR 3.3.1.1.11 SR 3.3.1.1.14 SR 3.3.1.1.15 SR 3.3.1.1.17 SR 3.3.1.1.18 (continued)

(a) With any control rod withdrawn from a core cell containing one or more fuel assemblies.

(b) Allowable values specified in COLR. Allowable value modification required by the COLR due to reduction in feedwater temperature may be delayed for up to 12 hours0.5 days 0.0714 weeks 0.0164 months .

(C) Within 30 days of uprate COLR 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 COLR.

RIVER BEND 3.3-7 Amendment No. 8-,97 1 ; 114 OCT 0 6 200

RPS Instrumentation 3.3.1.1 Table 3.3.1.1-1 (page 2 of 3)

Reactor Protection System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D.1 REQUIREMENTS VALUE

2. Average Power Range Monitors (continued)

c. Fixed Neutron 3 G SR 3.3.1.1.1 s 120% RTP Flux - High SR 3.3.1.1.2 SR 3.3.1.1.8 SR 3.3.1.1.9 SR 3.3.1.1.11 SR 3.3.1.1.15 SR 3.3.1.1.18

d. Inop 1,2 3 H SR 3.3.1.1.8 NA SR 3.3.1.1.9 SR 3.3.1.1.15 l 3. Reactor Vessel Steam Dome 1,2 2 H SR 3.3.1.1.1 5 1109.7 psig"'

Pressure - High SR 3.3.1.1.9 SR 3.3.1.1.10 SR 3.3.1.1.13 SR 3.3.1.1.15 SR 3.3.1.1.18

4. Reactor Vessel Water 1,2 2 H SR 3.3.1.1.1 2 8.7 inches Level - Low, Level 3 SR 3.3.1.1.9 SR 3.3.1.1.10 SR 3.3.1.1.13 SR 3.3.1.1.15 SR 3.3.1.1.18 I 5. Reactor Vessel Water Level - High, Level 8 2 23.8% RTP 2 F SR SR 3.3.1.1.1 3.3.1.1.9 s 52.1 inches SR 3.3.1.1.10 SR 3.3.1.1.13 SR 3.3.1.1.15 SR 3.3.1.1.18

6. Main Steam Isolation a G SR 3.3.1.1.9 s 12% closed Valve - Closure SR 3.3.1.1.13 SR 3.3.1.1.15 SR 3.3.1.1.18

7. Drywell Pressure-High 1,2 2 H SR 3.3.1.1.1 s 1.88 psid SR 3.3.1.1.9 SR 3.3.1.1.10 SR 3.3.1.1.13 SR 3.3.1.1.15 (continued)

(a) ALLOWABLE VALUE to remain as I 1079.7 psi until pressure increase portion of Power Uprate.

RIVER BEND 3.3-8 Amendment No. B. 114 OCT C 6 203J

RPS Instrumentation 3.3.1.1 Table 3.3.1.1-1 (page 3 of 3)

Reactor Protection System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION D.1 REQUIREMENTS VALUE

8. Scram Discharge Volume Water Level-High

a. Transmitter/Trip Unit 1,2 2 H SR 3.3.1.1.1 s 53 inches SR 3.3.1.1.9 for LISN601A, B SR 3.3.1.1.10 s 51.7 inches SR 3.3.1.1.13 for LISN601C, D SR 3.3.1.1.15 5Ca) 2 I SR 3.3.1.1.1 s 53 inches SR 3.3.1.1.9 for LISN601A, B SR 3.3.1.1.10 S 51.7 inches SR 3.3.1.1.13 for LISN601C, D SR 3.3.1.1.15

b. Float Switch 1,2 2 H SR 3.3.1.1.9 S 53.5 inches SR 3.3.1.1.13 for LSNO13A, B SR 3.3.1.1.15 S 49 inches for LSN013C, D 5Ca) 2 I SR 3.3.1.1.9 S 53.5 inches SR 3.3.1.1.13 for LSN013A, B SR 3.3.1.1.15 s 49 inches for LSNO13C, D

9. Turbine Stop Valve Closure 2 40X RTP 4 E SR 3.3.1.1.9 S 7X closed SR 3.3.1.1.10 SR 3.3.1.1.13 SR 3.3.1.1.15 SR 3.3.1.1.16 SR 3.3.1.1.18

10. Turbine Control Valve k 40X RTP 2 E SR 3.3.1.1.9 2 465 psig Fast Closure, Trip Oil SR 3.3.1.1.10 Pressure - Low SR 3.3.1.1.13 SR 3.3.1.1.15 SR 3.3.1.1.16 SR 3.3.1.1.18

11. Reactor Mode 1.2 2 H SR 3.3.1.1.12 NA Switch -Shutdown Position SR 3.3.1.1.15 5 (a) 2 I SR 3.3.1.1.12 NA SR 3.3.1.1.15

12. Manual Scram 1,2 2 H SR 3.3.1.1.5 NA SR 3.3.1.1.15 5 (a) 2 I SR 3.3.1.1.5 NA SR 3.3.1.1.15 (a) With any control rod withdrawn from a core cell containing one or more fuel assemblies.

RIVER BEND 3 .3-9 Amendment No. 81

SRM Instrumentation 3.3.1.2 3.3 INSTRUMENTATION 3.3.1.2 Source Range Monitor (SRM) Instrumentation LCO 3.3.1.2 The SRM instrumentation in Table 3.3.1.2-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.1.2-1.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Restore required SRMs 4 hours0.167 days 0.0238 weeks 0.00548 months SRMs inoperable in to OPERABLE status.

MODE 2 with intermediate range monitors (IRMs) on Range 2 or below.

B. Three required SRMs B.1 Suspend control rod Immediately inoperable in MODE 2 withdrawal.

with IRMs on Range 2 or below.

C. Required Action and C.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months associated Completion Time of Condition A or B not met.

D. One or more required D.1 Fully insert all 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months SRMs inoperable in insertable control MODE 3 or 4. rods.

AND (continued)

RIVER BEND 3.3-10 Amendment No. 81

SRM Instrumentation 3.3.1.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. (continued) D.2 Place reactor mode switch 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months in the shutdown position.

E. One or more required E.1 Suspend CORE Immediately SRMs inoperable in ALTERATIONS except for MODE 5. control rod insertion.

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

RIVER BEND 3.3-11 Amendment No. 34- 161

SRM Instrumentation 3.3.1.2 SURVEILLANCE REQUIREMENTS

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

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

SURVEILLANCE FREQUENCY SR 3.3.1.2.1 Perform CHANNEL CHECK. 12 hours0.5 days 0.0714 weeks 0.0164 months SR 3.3.1.2.2 ------------------NOTES------------------

1. Only required to be met during CORE ALTERATIONS.

2. One SRM may be used to satisfy more than one of the following.

Verify an OPERABLE SRM detector is 12 hours0.5 days 0.0714 weeks 0.0164 months located in:

a. The fueled region;

b. The core quadrant where CORE ALTERATIONS are being performed when the associated SRM is included in the fueled region; and

c. A core quadrant adjacent to where CORE ALTERATIONS are being performed, when the associated SRM is included in the fueled region.

SR 3.3.1.2.3 Perform CHANNEL CHECK. 24 hours1 days 0.143 weeks 0.0329 months (continued)

RIVER BEND 3.3-12 Amendment No. 81

SRM Instrumentation 3.3.1.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.2.4 ----------------------------NOTE-----------------------------

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: 12 hours0.5 days 0.0714 weeks 0.0164 months during CORE

a. z 3.0 cps, or ALTERATIONS

b. z 0.7 cps with a signal to noise ratio z 2:1. AND 24 hours1 days 0.143 weeks 0.0329 months SR 3.3.1.2.5 ---------------------------NOT E------------------------------

Not required to be performed until 12 hours0.5 days 0.0714 weeks 0.0164 months after IRMs on Range 2 or below.

Perform CHANNEL FUNCTIONAL TEST. 31 days SR 3.3.1.2.6 ------------------------NOTES-------------------------------

1. Neutron detectors are excluded.

2. Not required to be performed until 12 hours0.5 days 0.0714 weeks 0.0164 months after IRMs on Range 2 or below.

Perform CHANNEL CALIBRATION. 24 months RIVER BEND 3.3-13 Amendment No. ~, 168

SRM Instrumentation 3.3.1.2 Table 3.3.1.2-1 (page 1 of 1)

Source Range Monitor Instrumentatioon APPLICABLE MWES OR OTHER REQUIRED SURVEILLANCE FUNCTION SPECIFIED CONDtTIONS CHANNELS REQUIREMENTS

-

1. Source Range Monitor 2(a) 3 SR 3.3.1.2.1 SR 3.3.1.2.4 SR 3.3.1.2.5 SR 3.3.1.2.6 3.4 2 SR 3.3.1.2.3 SR 3.3.1.2.4 SR 3.3.1.2.5 SR 3.3.1.2.6 5 SR 3.3.1.2.1 SR 3.3.1.2.2 SR 3.3.1.2.4 SR 3.3.1.2.5 SR 3.3.1.2.6 (a) With IRMs on Range 2 or below.

(b) Only one SRM channel Is required to be OPERABLE during spiral offload or reload when the fueled region includes only that SRM detector.

(c) Special movable detectors may be used In place of SRMs if connected to normal SRH circuits.

RIVER BEND 3 .3-14 Amendment No. 81

PBDS 3.3.1.3 3.3 INSTRUMENTATION 3.3.1.3 Period Based Detection System (PBDS)

LCO 3.3.1.3 One channel of PBDS instrumentation shall be OPERABLE.

AND Each OPERABLE channel-of PBDS instrumentation shall not indicate Hi-Hi DR Alarm.

APPLICABILITY: THERMAL POWER and core flow in the Restricted Region specified in the COLR.

THERMAL POWER and core flow in the Monitored Region specified in the COLR.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Any OPERABLE PBDS A.1 Place the reactor Immediately channel indicating Hi- modeswitch in the Hi DR Alarm. shutdown position.

(continued)

RIVER BEND 3.3-14a Amendment No. 106 MAY o 5 1999 fS

PBDS 3.3.1.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required PBDS channel B.1 --------NOTE----------

inoperable while in Only applicable if RPS the Restricted Function 2.b. APRM Flow Region. Biased Simulated Thermal Power High. Allowable Value is "Setup".

Initiate action to exit Immediately the Restricted Region.

OR B.2 Place the reactor mode Immediately switch in the shutdown position.

C. Required PBDS channel C.1 Initiate action to exit 15 minutes inoperable while in the Monitored Region.

the Monitored Region.

RIVER BEND 3.3-14b Amendment No. 106 MAY 0 5 1399

-shatt M I p e wt k d a 1l 2$f t 1 I , L~ 3

PBDS 3.3.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.1.3.1 Verify each OPERABLE channel of PBDS 12 hours0.5 days 0.0714 weeks 0.0164 months instrumentation not in Hi-Hi DR Alarm.

SR 3.3.1.3.2 Perform CHANNEL CHECK. 12 hours0.5 days 0.0714 weeks 0.0164 months SR 3.3.1.3.3 Perform CHANNEL FUNCTIONAL TEST. 24 months RIVER BEND 3.3-14c Amendment No.106 MAY 0 5 1999 Iee ,2&/h dLg8

Control Rod Block Instrumentation 3.3.2.1 3.3 INSTRUMENTATION 3.3.2.1 Control Rod Block Instrumentation LCO 3.3.2.1 The control rod block instrumentation for each Function in Table 3.3.2.1-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.2.1-1.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more rod A.1 Suspend control rod Immediately withdrawal limiter withdrawal.

(RWL) channels inoperable.

B. One or more rod B.1 Suspend control rod Immediately pattern controller movement except by channels inoperable. scram.

C. One or more Reactor C.1 Suspend control rod Immediately Mode Switch-Shutdown withdrawal.

Position channels inoperable. AND C.2 Initiate action to Immediately fully insert all insertable control rods in core cells containing one or more fuel assemblies.

RIVER BEND 3.3-15 Amendment No. 81

Control Rod Block Instrumentation 3.3.2.1 SURVEILLANCE REQUIREMENTS

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

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 hours0.25 days 0.0357 weeks 0.00822 months provided the associated Function maintains control rod block capability.

SURVEILLANCE FREQUENCY SR 3.3.2.1.1 ------------------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 THERMAL POWER is greater than the RWL high power setpoint (HPSP).

Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.2.1.2 ------------------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 THERMAL POWER is > 35% RTP and less than or equal to the RWL HPSP.

Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.2.1.3 ------------------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 in MODE 2.

Perform CHANNEL FUNCTIONAL TEST. 92 days (continued)

RIVER BEND 3.3-16 Amendment No. 81

Control Rod Block Instrumentation 3.3.2.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.2.1.4 ----------------------------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 THERMAL POWER is :os; 10% RTP in MODE 1.

Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.2.1.5 Calibrate the low power setpoint trip units. The 92 days Allowable Value shall be > 10% RTP and

os; 35% RTP.

SR 3.3.2.1.6 Verify the RWL high power Function is not 92 days bypassed when THERMAL POWER is

> 68.2% RTP.

SR 3.3.2.1.7 Perform CHANNEL CALIBRATION. 184 days SR 3.3.2.1.8 ------------------------------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 reactor mode switch is in the shutdown position.

Perform CHANNEL FUNCTIONAL TEST. 24 months 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, 168

- -

Control Rod Block Instrumentation 3.3.2.1 Table 3.3.2.1-1 (page 1 of 1)

Control Rod Block Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE FUNCTION CONDITIONS CHANNELS REQUIREMENTS

1. Rod Pattern Control System

a. Rod withdrawal limiter (a) 2 SR 3.3.2.1.1 SR 3.3.2.1.6 SR 3.3 1 1 0 (b) 2 SR 3.3.2.1.2 SR 3.3.2.1.5 SR 3.3.2.1.7 SR 3.3.2.1.9

b. Rod pattern controller 1 (C).2 2 SR 3.3.2.1.3 SR 3.3.2.1.4 SR 3.3.2.1.5 SR 3.3.2.1.7 SR 3.3.2.1.9

2. Reactor Mode Switch -Shutdown Position (d) 2 SR 3.3.2.1.8 I

(a) THERMAL POWER greater than the HPSP.

(b) THERMAL POWER > 35% RTP and less than or equal to the HPSP.

I (c) With THERMAL POWER i 10 RTP.

(d) Reactor mode switch in the shutdown position.

RIVER BEND 3.3-18 Amendment No. 81-. 118

PAM Instrumentation 3.3.3.1 3.3 INSTRUMENTATION 3.3.3.1 Post Accident Monitoring (PAM) Instrumentation LCO 3.3.3.1 The PAM instrumentation for each Function in Table 3.3.3.1-1 shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS

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

Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more Functions A.1 Restore required channel 30 days with one required channel to OPERABLE status.

inoperable.

B. Required Action and B.1 Initiate action to prepare Immediately associated Completion and submit a Special Time of Condition A not Report.

met.

C. One or more Functions C.1 Restore one required 7 days with two required channels channel to OPERABLE inoperable. status.

(continued)

RIVER BEND 3.3-19 Amendment No. 81, 156

PAM Instrumentation 3.3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Enter the Condition Immediately associated Completion referenced in Time of Condition C Table 3.3.3.1-1 for not met. the channel.

E. As required by E.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months Required Action D.1 and referenced in Table 3.3.3.1-1.

F. As required by F.1 Initiate action to Immediately Required Action D.1 prepare and submit a and referenced in Special Report.

Table 3.3.3.1-1.

RIVER BEND 3.3-20 Amendment No. 81

PAM Instrumentation 3.3.3.1 SURVEILLANCE REQUIREMENTS

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

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

SURVEILLANCE FREQUENCY SR 3.3.3.1.1 Perform CHAI\INEL CHECK. 31 days SR 3.3.3.1.2 Deleted SR 3.3.3.1.3 Perform CHANNEL CALIBRATION. 24 months RIVER BEND 3.3-21 Amendment No. 81 142, 168

PAM Instrumentation 3.3.3.1 Table 3.3.3.1-1 (page 1 of 1)

Post Accident Monitoring Instrumentation CONDITIONS REFERENCED FROM REQUIRED REQUIRED FUNCTION CHANNELS ACTION D.1

1. Reactor Steam Dome Pressure 2 E

2. Reactor Vessel Water Level - Wide Range 2 E

3. Reactor Vessel Water Level - Fuel Zone 2 E

4. Suppression Pool Water Level 2 E

5. Suppression Pool Sector Water Temperature 2(a) E

6. Drywell Pressure 2 E

7. Primary Containment Pressure 2 E

8. Drywell Area Radiation 2 F

9. Primary Containment Area Radiation 2 F

10. Deleted I 11.Deleted I

12. Penetration Flow Path, Automatic PCIV 2 per penetration E Position flow path (b)(c)

(a) Monitoring each of two sectors.

(b) Not required for isolation valves whose associated penetration flow path is isolated.

(c) Only one position indication channel is required for penetration flow paths with only one control room indication channel.

RIVER BEND 3.3-22 Amendment No. 84 AS, 142

Remote Shutdown System 3.3.3.2 3.3 INSTRUMENTATION 3.3.3.2 Remote Shutdown System 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 COMPLETION TIME A. One or more required A.1 Restore required Function 30 days Functions inoperable. to OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months associated Completion Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.3.2.1 Perform CHANNEL CHECK for each required 31 days instrumentation channel that is normally energized.

(continued)

RIVER BEND 3.3-23 Amendment No. 81, 156

Remote Shutdown System 3.3.3.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.3.2.2 Verify each required control circuit and transfer 24 months switch is capable of performing the intended functions.

SR 3.3.3.2.3 Perform CHANNEL CALIBRATION for each 24 months required instrumentation channel, except valve position instrumentation.

RIVER BEf'm 3.3-24 Amendment No. 8+, 168

EOC-RPT Instrumentation 3.3.4.1 3.3 INSTRUMENTATION 3.3.4.1 End of Cycle Recirculation Pump Trip (EOC-RPT) Instrumentation LCO 3.3.4.1 a. Two channels per trip system for each EOC-RPT instrumentation I Function listed below shall be OPERABLE:

1. Turbine Stop Valve (TSV) Closure; and

2. Turbine Control Valve (TCV) Fast Closure, Trip Oil Pressure-Low.

OR

b. LCO 3.2.2, 'MINIMUM CRITICAL POWER RATIO (MCPR),m and LCO 3.2.3, 'Linear Heat Generation Rate (LHGR)," limits for inoperable EOC-RPT as specified in the COLR are made applicable.

APPLICABILITY: THERMAL POWER 2 40% RTP with any recirculation pump in fast speed.

ACTIONS

A------------------NOTE---

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Restore channel to 72 hours3 days 0.429 weeks 0.0986 months channels inoperable. OPERABLE status.

OR A.2 -- N OTE---------

Not applicable if inoperable channel is the result of an inoperable breaker.

Place channel in trip. 72 hours3 days 0.429 weeks 0.0986 months (continued)

RIVER BEND 3.3-25 Amendment No. 9i-, 146 1

EOC-RPT Instrumentation 3.3.4.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One or more Functions B.1 Restore EOC-RPT trip 2 hours0.0833 days 0.0119 weeks 0.00274 months with EOC-RPT trip capability.

capability not maintained.

OR AND B.2 Apply the MCPR and 2 hours0.0833 days 0.0119 weeks 0.00274 months MCPR and LHGR limits for LHGR limits for inoperable EOC-RPT not inoperable EOC-RPT as made applicable. specified in the COLR.

C. Required Action and C.1 Remove the associated 4 hours0.167 days 0.0238 weeks 0.00548 months associated Completion recirculation pump fast Time not met. speed breaker from service.

OR C.2 Reduce THERMAL 4 hours0.167 days 0.0238 weeks 0.00548 months POWER to < 40% RTP.

RIVER BEND 3.3-26 Amendment No. 4, 146 l

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 hours0.25 days 0.0357 weeks 0.00822 months , provided the associated Function maintains EOC-RPT trip capability.

SURVEILLANCE FREQUENCY SR 3.3.4.1.1 Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.4.1.2 Calibrate the trip units. 92 days SR 3.3.4.1.3 Perform CHANNEL CALIBRATION. The Allowable 24 months Values shall be:

a. TSV Closure: ~ 7% closed.

b. TCV Fast Closure, Trip Oil Pressure Low: ~ 465 psig.

SR 3.3.4.1.4 Perform LOGIC SYSTEM FUNCTIONAL TEST, 24 months including breaker actuation.

SR 3.3.4.1.5 Verify TSV Closure and TCV Fast Closure, Trip Oil 24 months Pressure Low Functions are not bypassed when THERMAL POWER is ~ 40% RTP.

(continued)

RIVER BEND 3.3-27 Amendment No. 8-+, 168

EOC-RPT Instrumentation 3.3.4.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.4.1.6 ---------------------------NOTE------------------------------

Breaker interruption time may be assumed from the most recent performance of SR 3.3.4.1.7.

Verify the EOC-RPT SYSTEM RESPONSE TIME 24 months on a is within limits. STAGGERED TEST BASIS SR 3.3.4.1.7 Determine RPT breaker interruption time. 60 months RIVER BEND 3.3-28 Amendment No.~, 168

ATWS-RPT Instrumentation 3.3.4.2 3.3 INSTRUMENTATION 3.3.4.2 Anticipated Transient Without Scram Recirculation Pump Trip (ATWS-RPT) -Instrumentation LCO 3.3.4.2 Two channels per trip system for each ATWS-RPT instrumentation Function listed below shall be OPERABLE:

a. Reactor Vessel Water Level-Low Low, Level 2; and

b. Reactor Steam Dome Pressure-High.

APPLICABILITY: MODE 1.

ACTIONS

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

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Restore channel to 14 days inoperable. OPERABLE status.

OR A.2 --------NOTE---------

Not applicable if inoperable channel is the result of an inoperable breaker.

Place channel in 14 days trip.

(continued)

RIVER BEND 3.3-29 Amendment No. 81

ATWS-RPT Instrumentation 3.3.4.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One Function with B.1 Restore ATWS-RPT trip 72 hours3 days 0.429 weeks 0.0986 months ATWS-RPT trip capability.

capability not maintained.

C. Both Functions with C.1 Restore ATWS-RPT trip 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ATWS-RPT trip capability for one capability not Function.

maintained.

D. Required Action and D.1 Remove the associated 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion recirculation pump Time not met. from service.

OR 0.2 Be in MODE 2. 6 hours0.25 days 0.0357 weeks 0.00822 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 hours0.25 days 0.0357 weeks 0.00822 months provided the associated Function maintains ATWS-RPT trip capability.

SURVEILLANCE FREQUENCY SR 3.3.4.2.1 Perform CHANNEL CHECK. 12 hours0.5 days 0.0714 weeks 0.0164 months (continued)

RIVER BEND 3.3-30 Amendment No. 81

ATWS-RPT Instrumentation 3.3.4.2 SURVEILLANCE FREQUENCY SR 3.3.4.2.2 Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.4.2.3 Calibrate the trip units. 92 days SR 3.3.4.2.4 Perform CHANNEL CALIBRATION. The Allowable 24 months Values shall be:

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

b. Reactor Steam Dome Pressure-High:

s; 1165 psig.

SR 3.3.4.2.5 Perform LOGIC SYSTEM FUNCTIONAL TEST, 24 months including breaker actuation.

RIVER BEND 3.3-31 Amendment No. 81114,168

ECCS Instrumentation 3.3.5.1 3.3 INSTRUMENTATION 3.3.5.1 Emergency Core Cooling System (ECCS) Instrumentation LCO 3.3.5.1 The ECCS instrumentation for each Function in Table 3.3.5.1-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.5.1-1.

ACTIONS

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

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Enter the Condition Immediately inoperable. referenced in Table 3.3.5.1-1 for the channel.

B. As required by B.1 -------- NOTES--------

Required Action A.1 1. Only applicable and referenced in in MODES 1, 2, Table 3.3.5.1-1. and 3.

2. Only applicable for Functions 1.a, 1.b, 2.a and 2.b.

Declare supported 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from feature(s) inoperable discovery of when its redundant loss of feature ECCS initiation initiation capability capability for is inoperable. feature(s) in both divisions AND (continued)

RIVER BEND 3.3-32 Amendment No. 81

ECCS Instrumentation 3.3.5.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.2 ---- NOTES--------

1. Only applicable in MODES 1, 2, and 3.

2. Only applicable for Functions 3.a and 3.b.

Declare High Pressure 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from Core Spray (HPCS) discovery of System inoperable. loss of HPCS initiation AND capability B.3 Place channel in 24 hours1 days 0.143 weeks 0.0329 months trip.

C. As required by C.1 --------NOTES--------

Required Action A.1 1. Only applicable and referenced in in MODES 1, 2, Table 3.3.5.1-1. and 3.

2. Only applicable for Functions 1.c, 1.d, 1.e, 2.c, 2.d, and 2.e.

Declare supported 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from feature(s) inoperable discovery of when its redundant loss of feature ECCS - initiation initiation capability capability for is inoperable. feature(s) in both divisions AND (continued)

RIVER BEND 3.3-33 Amendment No. 81

ECCS Instrumentation 3.3.5.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. (continued) C.2 Restore channel to 24 hours1 days 0.143 weeks 0.0329 months OPERABLE status.

D. As required by D.1 --- NOTE---------

Required Action A.1 Only applicable if and referenced in HPCS pump suction is Table 3.3.5.1-1. not aligned to the suppression pool.

Declare HPCS System 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from inoperable. discovery of loss of HPCS initiation capability AND D.2.1 Place channel in 24 hours1 days 0.143 weeks 0.0329 months trip.

OR D.2.2 Align the HPCS pump 24 hours1 days 0.143 weeks 0.0329 months suction to the suppression pool.

(continued)

RIVER BEND 3.3-34 Amendment No. 81

ECCS Instrumentation 3.3.5.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. As required by E.1 --------NOTES--------

Required Action A.1 1. Only applicable

-- and referenced in in MODES 1, 2, Table 3.3.5.1-1. and 3.

2. Only applicable for Functions 1.f, 1.g, and 2.f.

Declare supported 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from feature(s) inoperable discovery of when its redundant loss of feature ECCS initiation initiation capability capability for is inoperable. feature(s) in both divisions AND E.2 Restore channel to 7 days OPERABLE status.

F. As required by F.1 Declare Automatic 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from Required Action A.1 Depressurization discovery of and referenced in System (ADS) valves loss of ADS Table 3.3.5.1-1. inoperable. initiation capability in both trip systems AND (continued)

RIVER BEND 3.3-35 Amendment No. 81

ECCS Instrumentation 3.3.5.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME F. (continued) F.2 Place channel in 96 hours4 days 0.571 weeks 0.132 months from trip. discovery of inoperable channel concurrent with HPCS or reactor core isolation cooling (RCIC) inoperable AND 8 days G. As required by G.1 -------- NOTE---------

Required Action A.1 Only applicable for and referenced in Functions 4.c, 4.e, Table 3.3.5.1-1. 4.f, 4.g, 5.c, 5.e, and 5.f.

Declare ADS-valves 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from inoperable. discovery of loss of ADS initiation capability in both trip systems AND (continued)

RIVER BEND 3.3-36 Amendment No. 81

-

ECCS Instrumentation 3.3.5.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME G. (continued) G.2 Restore channel to 96 hours4 days 0.571 weeks 0.132 months from OPERABLE status. discovery of inoperable channel concurrent with HPCS or RCIC inoperable AND 8 days H. Required Action and H.1 Declare associated Immediately associated Completion supported feature(s)

Time of Condition B, inoperable.

C, D, E, F, or G not met.

RIVER BEND 3.3-37 Amendment No. 81

ECCS Instrumentation 3.3.5.1 SURVEILLANCE REQUIREMENTS

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

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 hours0.25 days 0.0357 weeks 0.00822 months for Functions 3.c, 3.f, 3.g, and 3.h; and (b) for up to 6 hours0.25 days 0.0357 weeks 0.00822 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. 12 hours0.5 days 0.0714 weeks 0.0164 months SR 3.3.5.1.2 Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.5.1.3 Calibrate the trip unit. 92 days SR 3.3.5.1.4 Perform CHANNEL CALIBRATION. 92 days SR 3.3.5.1.5 Perform CHANNEL CALIBRATION. 24 months SR 3.3.5.1.6 Perform LOGIC SYSTEM FUNCTIONAL TEST. 24 months RIVER BEND 3.3-38 Amendment No. 8-+, 168

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 1 of 5)

Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES OR REFERENCED OTHER REQUIRED FROM SPECIFIED CHANNELS PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTION A.1 REQUIREMENTS VALUE

1. Low Pressure Coolant Injection-A (LPCI) and Low Pressure Core Spray (LPCS)

Subsystems

a. Reactor Vessel Water 2 (b) B SR 3.3.5.1.1 2 -147 Level - Low Low Low, 4(Id) 53('a) SR 3.3.5.1.2 inches Level 1 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6

b. Drywell Pressure-High 1,2,3 2 (b) B SR 3.3.5.1.1 s 1.88 psid SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6

c. LPCS Pump Start-Time 1,2,3, 1 C SR 3.3.5.1.2 k 1.8 Delay Relay 4 (a), 5 (a) SR 3.3.5.1.4 seconds and SR 3.3.5.1.6 S 2.2 seconds

d. LPCI Pump A 1,2,3, 1 C SR 3.3.5.1.2 2 6.3 Start-Time Delay 4 (a)65 (a) SR 3.3.5.1.4 seconds and Relay SR 3.3.5.1.6 s 7.7 seconds

e. Reactor Vessel 1,2,3 C SR 3.3.5.1.1 2 472 psig Pressure -Low SR 3.3.5.1.2 and (Injection Permissive) SR 3.3.5.1.3 S 502 psig SR 3.3.5.1.5 SR 3.3.5.1.6 4 (a),5(a) 4 B SR 3.3.5.1.1 ? 472 psig SR 3.3.5.1.2 and SR 3.3.5.1.3 S 502 psig SR 3.3.5.1.5 SR 3.3.5.1.6

f. LPCS Pump Discharge 1,2,3, 1 E SR 3.3.5.1.1 2 750 gpy Flow-Low (Bypass) 4 Ca),5 Ca) SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6

g. LPCI Pump A Discharge 1,2,3, 1 E SR 3.3.5.1.1 2 900 gpn Flow-Low (Bypass) 4 Ca) 5 Ca) SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6

h. Manual Initiation 1,2.3, 1 per system C SR 3.3.5.1.6 NA 4 C0) 5 Ma (continued) ta) When associated subsystemts) are required to be OPERABLE.

(b) Also required to initiate the associated diesel generator.

RIVER BEND 3.3 -39 Amendment No. 81

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 2 of 5)

Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES OR REFERENCED OTHER REQUIRED FROM SPECIFIED CHANNELS PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTION A.1 REQUIREMENTS VALUE

2. LPCI B and LPCI C Subsystems

a. Reactor Vessel Water 1,2,3, 2 (b) B SR 3.3.5.1.1 2 -147 Level -Low Low Low, SR 3.3.5.1.2 inches Level 1 4(a). 5 (a) SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6

b. Drywell Pressure-High 1,2,3 2 (b) B SR 3.3.5.1.1 s 1.88 psid SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6

c. LPCI Pump B 1,2,3, 1 C SR 3.3.5.1.2 2 6.3 Start-Time Delay SR 3.3.5.1.4 seconds and Relay 4(a), 5 (a) SR 3.3.5.1.6 s 7.7 seconds

d. LPCI PuTp C 1,2,3, 1 C SR 3.3.5.1.2 2 1.8 Start-Time Delay SR 3.3.5.1.4 seconds and Relay 4(a) 5 (a) SR 3.3.5.1.6 s 2.2 seconds

e. Reactor Vessel 1,2,3 C SR 3.3.5.1.1 2 472 psig Pressure - Low SR 3.3.5.1.2 and (Injection Permissive) SR 3.3.5.1.3 s 502 psig SR 3.3.5.1.5 SR 3.3.5.1.6 4(a),5 (a) B SR 3.3.5.1.1 2 472 psig SR 3.3.5.1.2 and SR 3.3.5.1.3 s 502 psig SR 3.3.5.1.5 SR 3.3.5.1.6

f. LPCI Pump B and LPCI 1,2,3, 1 per pump E SR 3.3.5.1.1 2 900 gpm Pump C Discharge SR 3.3.5.1.2 Flow-Low (Bypass) 4 (a), 5 (a) SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6

9. Manual Initiation 1,2,3, 1 C SR 3.3.5.1.6 NA 4 (a), 5 (a)

(continued)

(a) When associated subsystem(s) are required to be OPERABLE.

(b) Also required to initiate the associated diesel generator.

RIVER BEND 3 .3-40 Amendment No. 81

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 3 of 5)

Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES OR REFERENCED OTHER REQUIRED FROM SPECIFIED CHANNELS PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTION A.1 REQUIREMENTS VALUE

3. High Pressure Core Spray (HPCS) System

a. Reactor Vessel 1,2,3, 4 (b) B SR 3.3.5.1.1 k -47 inches Water Level - Low SR 3.3.5.1.2 Low, Level 2 4 Ca), 5 (a) SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6

b. Drywell 1,2,3 4 (b) B SR 3.3.5.1.1 s 1.88 psid Pressure - High SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6

c. Reactor Vessel 1,2,3, 2 C SR 3.3.5.1.1 s 55 Inches Water SR 3.3.5.1.2 Level - High, .(a),5(a) SR 3.3.5.1.3 Level 8 SR 3.3.5.1.5 SR 3.3.5.1.6

d. Condensate 1,2,3, 2 D SR 3.3.5.1.1 2 -4.5 inches Storage Tank SR 3.3.5.1.2 Level - Low 4 (c),5 (c) SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6

e. Suppression Pool 1,2,3 2 D SR 3.3.5.1.1 s 8 inches Water Level -High SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6

f. HPCS Pump 1,2,3, 1 E SR 3.3.5.1.1 2 275 psig Discharge SR 3.3.5.1.2 Pressure - High (a), 5 (a) SR 3.3.5.1.3 (Bypass) SR 3.3.5.1.5 SR 3.3.5.1.6

g. HPCS System Flow 1,2,3, I E SR 3.3.5.1.1 2 710 gpm Rate - Low SR 3.3.5.1.2 (Bypass) 4 (a), 5 ta) SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6

h. Manual Initiation 1,2,3, 1 C SR 3.3.5.1.6 NA 4 (a),5 (a)

(continued)

(a) When associated subsystem(s) are required to be OPERABLE.

(b) Also required to initiate the associated diesel generator.

(c) When HPCS is OPERABLE for compliance with LCO 3.5.2, "ECCS- Shutdown," and aligned to the condensate storage tank while tank water level is not within the limit of SR 3.5.2.2.

RIVER BEND 3.3-41 Amendment No. 81

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 4 of 5)

Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES OR REFERENCED OTHER REQUIRED FROM SPECIFIED CHANNELS PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTION A.1 REQUIREMENTS VALUE

4. Automatic Depressurization System (ADS) Trip System A

a. Reactor Vessel j 2 (d), 3 (d) 1 2 F SR 3.3.5.1.1 2 -147 inches Water LeveL-Low SR 3.3.5.1.2 Low Low, Level 1 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6

b. Drywell 1 , 2 (d), 3 (d) 2 F SR 3.3.5.1.1 S 1.88 psid Pressure - High SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6

c. ADS Initiation 1 ,2(d), 3 0d) 1 G SR 3.3.5.1.2 S 117 seconds Timer SR 3.3.5.1.4 SR 3.3.5.1.6

d. Reactor Vessel 1 , 2 (d), 3 (d) 1 F SR 3.3.5.1.1 2 8.7 inches Water Level -Low, SR 3.3.5.1.2 Level 3 SR 3.3.5.1.3 (Confirmatory) SR 3.3.5.1.5 SR 3.3.5.1.6

e. LPCS Pump 1 , 2 (d), 3 0d) 2 G SR 3.3.5.1.1 2 130 psig Discharge SR 3.3.5.1.2 Pressure- High SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6

f. LPCI Puzrp A 1 ,2(d). 3 (d) 2 G SR 3.3.5.1.1 2 120 psig Discharge SR 3.3.5.1.2 Pressure- High SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6 B. ADS Bypass Timer 1 ,2(d) 3 (d) 2 G SR 3.3.5.1.2 S 5.5 minutes (High Drywelt SR 3.3.5.1.4 Pressure) SR 3.3.5.1.6

h. Manual Initiation 1 12 (d), 3 (d) 2 per system G SR 3.3.5.1.6 NA (continued)

(d) With reactor steam dome pressure > 100 psig.

RIVER BEND 3.3-42 Amendment No. 81

ECCS Instrumentation 3.3.5.1 Table 3.3.5.1-1 (page 5 of 5)

Emergency Core Cooling System Instrumentation APPLICABLE CONDITIONS MODES OR REFERENCED OTHER REQUIRED FROK SPECIFIED CHANNELS PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS FUNCTION ACTION A.1 REQUIREMENTS VALUE

5. ADS Trip System B

a. Reactor Vessel Water 1 ,2 (d),3 (d) 2 F SR 3.3.5.1.1 2 -147 Level - Low Low Low, SR 3.3.5.1.2 inches Level 1 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6

b. Drywell Pressure -High 1 ,2 (d),3 (d) 2 F SR 3.3.5.1.1 s 1.88 psid SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6

c. ADS Initiation Timer 1 ,2 (d),3 (d) 1 G SR 3.3.5.1.2 S 117 SR 3.3.5.1.4 seconds SR 3.3.5.1.6

d. Reactor Vessel Water 1 ,2 (d),3 (d) 1 F SR 3.3.5.1.1 2 8.7 inches Level -Low, Level 3 SR 3.3.5.1.2 (Confirmatory) SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6

e. LPCI Pumps B & C 1 ,2 (d),3 (d) 2 per pump G SR 3.3.5.1.1 2 120 psig Discharge SR 3.3.5.1.2 Pressure - High SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6

f. ADS Bypass Timer (High 1 ,2 (d),3 (d) 2 G SR 3.3.5.1.2 S 5.5 Drywel. Pressure) SR 3.3.5.1.4 minutes SR 3.3.5.1.6 B. ManuaL Initiation 1 .2 (d),3 (d) 2 per system G SR 3.3.5.1.6 NA (d) With reactor steam dome pressure > 100 psig.

RIYER BEND 3.3-43 Amendment No. 81

-

RCIC System Instrumentation 3.3.5.2 3.3 INSTRUMENTATION 3.3.5.2 Reactor Core Isolation Cooling (RCIC) System Instrumentation LCO 3.3.5.2 The RCIC System instrumentation for each Function in Table 3.3.5.2-1 shall be OPERABLE.

APPLICABILITY: MODE 1, MODES 2 and 3 with reactor steam dome pressure > 150 psig.

ACTIONS

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

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION, COMPLETION TIME A. One or more channels A.1 Enter the Condition Immediately inoperable. referenced in Table 3.3.5.2-1 for the channel.

B. As required by B.1 Declare RCIC System 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from Required Action A.1 inoperable. discovery of and referenced in loss of RCIC Table 3.3.5.2-1. initiation capability AND B.2 Place channel in 24 hours1 days 0.143 weeks 0.0329 months trip.

C. As required by C.1 Restore channel to 24 hours1 days 0.143 weeks 0.0329 months Required Action A.1 OPERABLE status.

and referenced in Table 3.3.5.2-1.

(continued)

RIVER BEND 3.3-44 Amendment No. 81

RCIC System Instrumentation 3.3.5.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. As required by D.1 --- NOTE---------

Required Action A.1 Only applicable if and referenced in RCIC pump suction is Table 3.3.5.2-1. not aligned to the suppression pool.

Declare RCIC System 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from

.inoperable. discovery of loss of RCIC initiation capability AND D.2.1 Place channel in 24 hours1 days 0.143 weeks 0.0329 months trip.

OR D.2.2 Align RCIC pump 24 hours1 days 0.143 weeks 0.0329 months suction to the suppression pool.

E. Required Action and E.1 Declare RCIC System Immediately associated Completion inoperable.

Time of Condition B, C, or D not met.

RIVER BEND 3. 3-45 Amendment No. 81

RCIC System Instrumentation 3.3.5.2 SURVEILLANCE REQUIREMENTS

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

1. Refer to Table 3.3.5.2-1 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 hours0.25 days 0.0357 weeks 0.00822 months for Functions 2 and 5; and (b) for up to 6 hours0.25 days 0.0357 weeks 0.00822 months for Functions 1, 3, and 4 provided the associated Function maintains RCIC initiation capability.

SURVEILLANCE FREQUENCY SR 3.3.5.2.1 Perform CHANNEL CHECK. 12 hours0.5 days 0.0714 weeks 0.0164 months SR 3.3.5.2.2 Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.5.2.3 Calibrate the trip units. 92 days SR 3.3.5.2.4 Perform CHANNEL CALIBRATION. 24 months SR 3.3.5.2.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. 24 months RIVER BEND 3.3-46 Amendment No. 8-+, 168

RCIC System Instrumentation 3.3.5.2 Table 3.3.5.2-1 (page 1 of 1)

Reactor Core Isolation Cooling System Instrunentation CONDITIONS REQUIRED REFERENCED CHANNELS PER FROM-REQUIRED SURVEILLANCE ALLOWABLE FUNCTION FUNCTION ACTION A.1 REQUIREMENTS VALUE

1. Reactor Vessel Water 4 B SR 3.3.5.2.1 2 -47 inches Level - Low Low, Level 2 SR 3.3.5.2.2 SR 3.3.5.2.3 SR 3.3.5.2.4 SR 3.3.5.2.5

2. Reactor Vessel Water 2 C SR 3.3.5.2.1 S 52 inches Level -High, Level 8 SR 3.3.5.2.2 SR 3.3.5.2.3 SR 3.3.5.2.4 SR 3.3.5.2.5

3. Condensate Storage Tank 2 D SR 3.3.5.2.1 2 -4.5 inches Level - Low SR 3.3.5.2.2 SR 3.3.5.2.3 SR 3.3.5.2.4 SR 3.3.5.2.5

4. Suppression Pool Water 2 D SR 3.3.5.2.1 S 8 inches Level - High SR 3.3.5.2.2 SR 3.3.5.2.3 SR 3.3.5.2.4 SR 3.3.5.2.5

5. Manual Initiation 1 C SR 3.3.5.2.5 NA RIVER BEND 3.3-47 Amendment No. 81

Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 3.3 INSTRUMENTATION 3.3.6.1 Primary Containment and Dryweilisolation Instrumentation LCO 3.3.6.1 The primary containment and drywell isolation instrumentation for each Function in Table 3.3.6.1-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.6.1-1.

ACTIONS

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

1. Penetration flow paths, except for the drywell 24 inch purge valve penetration flow path, may be unisolated intermittently under administrative controls.

2. Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Place channel in trip. 12 hours0.5 days 0.0714 weeks 0.0164 months for channels inoperable. Functions 2.b, 5.b, 5.d, and 5.e AND 24 hours1 days 0.143 weeks 0.0329 months for Functions other than Functions 2.b, 5.b, 5.d, and 5.e B. One or more automatic B.1 Restore isolation 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Functions with isolation capability.

capability not maintained.

(continued)

RIVER BEND 3.3-48 Amendment No. &+, 165

Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Enter the Condition Immediately associated Completion referenced in Time of Condition A Table 3.3.6.1-1 for or B not met. the channel.

D. As required by D.1 Isolate associated 12 hours0.5 days 0.0714 weeks 0.0164 months Required Action C.1 main steam line and referenced in (MSL).

Table 3.3.6.1-1.

OR D.2.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months AND D.2.2 Be in MODE 4. 36 hours1.5 days 0.214 weeks 0.0493 months E. As required by E.1 Be in MODE 2. 6 hours0.25 days 0.0357 weeks 0.00822 months Required Action C.1 and referenced in Table 3.3.6.1-1.

F. As required by F.1 Isolate the affected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Required Action C.1 penetration flow and referenced in path(s).

Table 3.3.6.1-1.

G. As required by G.1 Isolate the affected 24 hours1 days 0.143 weeks 0.0329 months Required Action C.1 penetration flow and referenced in path(s).

Table 3.3.6.1-1.

(continued)

RIVER BEND 3.3-49 Amendment No. 81

Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME H. As required by H.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months Required Action C.1 and referenced in AND Table 3.3.6.1-1.

H.2 Be in MODE 4. 36 hours1.5 days 0.214 weeks 0.0493 months OR Required Action and associated Completion Time of Condition F or G not met.

I. As required by 1.1 Declare associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Required Action C.1 standby liquid and referenced in control subsystem Table 3.3.6.1-1. inoperable.

OR 1.2 Isolate the Reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Water Cleanup System.

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

Table 3.3.6.1-1.

OR J.2 Initiate action to Immediately isolate the Residual Heat Removal (RHR)

Shutdown Cooling System suction from the reactor vessel.

OR (continued)

RIVER BEND 3.3-50 Amendment No. 81

Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME J. (continued) J.3.1 Initiate action to Immediately restore primary containment to OPERABLE status.

AND J.3.2 -------- NOTE---------

Entry and exit is permissible under administrative control.

Initiate action to Immediately close one door in each primary containment air lock.

K. As required by K.1 Isolate the affected Immediately Required Action C.1 penetration flow and referenced in path(s).

Table 3.3.6.1-1.

OR K.2.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months AND K.2.2 Be in MODE 4. 36 hours1.5 days 0.214 weeks 0.0493 months RIVER BEND 3.3-51 Amendment No. 81

Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 SURVEILLANCE REQUIREMENTS

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

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 hours0.25 days 0.0357 weeks 0.00822 months , provided the associated Function maintains isolation capability.

SURVEILLANCE FREQUENCY SR 3.3.6.1.1 Perform CHANNEL CHECK. 12 hours0.5 days 0.0714 weeks 0.0164 months SR 3.3.6.1.2 Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.6.1.3 Calibrate the trip unit. 92 days SR 3.3.6.1.4 Perform CHANNEL CALIBRATION. 92 days SR 3.3.6.1.5 Perform CHANNEL CALIBRATION. 24 months SR 3.3.6.1.6 Perform LOGIC SYSTEM FUNCTIONAL TEST. 24 months SR 3.3.6.1.7 -----------------------------NOTE----------------------------

Channel sensors are excluded.

Verify the ISOLATION SYSTEM RESPONSE TIME 24 months on a for the Main Steam Isolation Valves is within limits. STAGGERED TEST BASIS RIVER BEND 3.3-52 Amendment No. g.+, 168

Primary Containment and Dryweliisolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 1 of 5)

Primary Containment and Dryweilisolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION C.l REQUIREMENTS VALUE

1. Main Steam Line Isolation

a. Reactor Vessel Water 1,2,3 2 D SR 3.3.6.1.1 ;;: *147 Inches Level-Low Low Low, Level 1 SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6 SR 3.3.6.1.7

b. Main Steam Line Pressure -Low 2 E SR 3.3.6.1.1 ~ 837 psig SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6 SR 3.3.6.1.7

c. Main Steam Line Flow-High 1,2,3 2 per MSL D SR 3.3.6.1.1 <:;190 psid, SR 3.3.6.1.2 LineA SR 3.3.6.1.3 <:;194 psid, SR 3.3.6.1.5 Line B SR 3.3.6.1.6 <:;194 psid.

SR 3.3.6.1.7 Line C

<:; 194 psid.

Line D

d. Condenser Vacuum-Low 1,2(a), 2 D SR 3.3.6.1.1 ;;: 7.6 inches SR 3.3.6.1.2 Hgvacuum SR 3.3.6.1.3 31a )

SR 3.3.6.1.5 SR 3.3.6.1.6

e. Main Steam Tunnel 1,2,3 2 D SR 3.3.6.1.1 <:;183°F Temperature-High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6

f. deleted

g. deleted

h. deleted (continued)

(a) With any turbine stop valve not closed.

RIVER BEND 3.3-53 Amendment No. 81 114 124 174 I

Primary Containment and Drywell Isolation Instrumentation

. 3.3.6.1 Table 3.3.6.1-1 (page 2 of 5)

Primary Containment and Drywenl Isolation Instrumentation APPLICABLE CONDmONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION C.A REQUIREMENTS VALUE

1. Main Steam LUne Isolation (continued)

L deleted I j Manual Initiation 1.2.3 2 G SR 3.3.6.1.6 NA

2. Primary Containment and Drywell Isolation

a. ReactorVesselWater 1.2.3 2 (b) H SR 3.3.6.1.1 2-47inches Level-Low Low, Level 2 SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6

b. Drywell Pressure-High 1.2,3 2tb) H SR 3.3.6.1.1 s 1.88 psid SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6

c. Contahiment Purge Isolation 1,2,3 1 K SR 3.3.6.1.1 S 1.57 Rllr Radiation-High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6

d. Manual Initiation 1.2,3 2(b) G SR 3.3.6.1.6 NA

3. Reactor Core Isolation Cooling (RCIC)

System Isolation

a. RCIC Steam Line Flow-High 1.2.3 1 F SR 3.3.6.1.1 s 13S.5 hiches SR 3.3.6.1.2 water SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6

b. RCIC Steam Line Flow 1.2,3 1 F SR 3.3.6.1.2 2 3 seconds Time Delay SR 3.3.6.1. and SR 3.3.6.1.6 S 13 seconds

c. RCIC Steam Supply Lne 1.2,3 1 F SR 3.3.6.1.1 2 55 psig Pressure-Low SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6 (continued)

(b) Also required to hiitiate the associated drywell Isolation function.

RIVER BEND 3.3-54 Amendment No. 8-4-, 124 JUL 11 2002

Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 Table 3.3.6.1*1 (page 3 of 5)

Primary Containment and Drywell Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION C.1 REQUIREMENTS VALUE

3. RCIC System Isolation (continued)

d. RCIC Turbine Exhaust 1.2.3 2 F SR 3.3.6.1.1 ~ 20 psig Diaphragm Pressure-High SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6

e. RCIC Equipment Room 1,2,3 F SR 3.3.6.1.1 ::;186.4°F Ambient Temperature-High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6

f. Main Steam Line Tunnel 1,2,3 F SR 3.3.6.1.1 ::; 183°F Ambient Temperature -High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6

g. Main Steam Line Tunnel 1,2,3 F SR 3.3.6.1.2 NA Temperature Timer SR 3.3.6.1.4 SR 3.3.6.1.6

h. RHR Equipment Room 1,2,3 F SR 3.3.6.1.1 ::;121.1°F Ambient Temperature-High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 RCIC/RHR Steam Une 1.2,3 F SR 3.3.6.1.1 :S 64.2 Inches water Flow-High SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6

j. Drywell Pressure-High 1,2,3 F SR 3.3.6.1.1 ::; 1.88 psid SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6

k. Manual Initiation 1,2.3 G SR 3.3.6.1.6 NA (continued)

RIVER BEND 3.3-55 Amendment No. 84,174

Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 4 of 5)

Primary Containment and Dryweilisolation Instrumentation APPLICABLE CONDITIONS MODES OR REFERENCED OTHER REQUIRED FROM SPECIFIED CHANNELS PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS TRIP SYSTEM ACTION C.1 REQUIREMENTS VALUE

4. Reactor Water Cleanup (RWCU)

System Isolation

a. Differential Flow-High 1,2,3 F SR 3.3.6.1.1 ,; 62.1 gpm SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6

b. Differential Flow-Timer 1,2,3 F SR 3.3.6.1.2 ,; 47 seconds SR 3.3.6.1.4 SR 3.3.6.1.6

c. RWCU Heat Exchanger 1,2,3 F SR 3.3.6.1.1 ,; 107.5°F Equipment Room SR 3.3.6.1.2 Temperature-High SR 3.3.6.1.5 SR 3.3.6.1.6

d. RWCU Pump Rooms 1,2,3 F SR 3.3.6.1.1 ,; 169.5°F Temperature-High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6

e. RWCU Valve Nest Room 1,2,3 F SR 3.3.6.1.1 ,; 114.5°F Temperature-High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6

f. RWCU Demineralizer Rooms 1,2,3 F SR 3.3.6.1.1 ,; 114,SOF Temperature-High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6

g. RWCU Receiving Tank Room 1,2,3 F SR 3.3.6.1.1 ,; 114.5°F Temperature-High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6

h. Main Steam Line Tunnel 1,2,3 F SR 3.3.6.1.1 ,; 183°F Ambient Temperature-High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 Reactor Vessel Water 1,2,3 2 F SR 3.3.6.1.1 ,,- 47 Inches Level-Low Low, Level 2 SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6

j. Standby Liquid Control System 1,2 SR 3.3.6.1.6 NA Initiation

k. Manual Initiation 1,2,3 2 G SR 3.3.6.1.6 NA (continued)

RIVER BEND 3.3-56 Amendment No. 8-+,174

Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 5 of 5)

Primary Containment and Drywell Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REFERENCED OTHER REQUIRED FROM SPECIFIED CHANNELS PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS TRIP SYSTEM ACTION C.1 REOUIREMENTS VALUE

5. RHR System Isolation

a. RHR Equipment Room 1,2.3 2 F SR 3.3.6.1.1 z 121.1F Ambient SR 3.3.6.1.2 Temperature - High SR 3.3.6.1.5 SR 3.3.6.1.6

b. Reactor Vessel Water 1 ,2,3(c) 2 F SR 3.3.6.1.1 2 8.7 inches Level - Low, Level 3 SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6 3(d),4,5 2Ce)

" SR 3.3.6.1.1 2 8.7 inches SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6

c. Reactor Vessel Water 1,2,3 2 F SR 3.3.6.1.1 2 -147 inches Level - Low Low Low, SR 3.3.6.1.2 Level 1 SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6

d. Reactor Steam Dome 1,2,3 2 F SR 3.3.6.1.1 s 150 psig Pressure - High SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6

e. Drywell Pressure-High 1,2,3 2 F SR 3.3.6.1.1 s 1.88 psid SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6

f. Manual Initiation 1,2,3 2 G SR 3.3.6.1.6 NA cc) With reactor steam dome pressure greater than or equal to the RHR cut-in permissive pressure.

(d) With reactor steam dome pressure less than the RHR cut-in permissive pressure.

(e) Only one trip system required in MODES 4 and 5 with RHR Shutdown Cooling System integrity maintained.

RIVER BEND 3.3-57 Amendment No. 81

I Secondary Containment and Fuel Building Isolation Instrumentation 3.3.6.2 3

3.3 INSTRUMENTATION l 3.3.6.2 Secondary Containment and Fuel Building Isolation Instrumentation I LCO 3.3.6.2 The isolation instrumentation for each Function in Table 3.3.6.2-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.6.2-1.

ACTIONS

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

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Place channel in trip. 12 hours0.5 days 0.0714 weeks 0.0164 months for inoperable. Function 2 AND 24 hours1 days 0.143 weeks 0.0329 months for Functions other than Function 2 I B. One or more automatic B.1 Restore the applicable 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Functions with secondary isolation capability.

I containment or fuel I building isolation capability not maintained.

C. Required Action and C.1.1 Isolate the associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated Completion penetration flow Time of Condition A or B path(s).

not met.

OR (continued)

RIVER BEND 3.3-58 Amendment No. 8F-.113

I Secondary Containment and Fuel Building Isolation Instrumentation 3.3.6.2 s ACTIONS 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------------------------------------

I 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 hours0.25 days 0.0357 weeks 0.00822 months , provided the associated Function maintains secondary containment isolation capability.

SURVEILLANCE FREQUENCY SR 3.3.6.2.1 Perform CHANNEL CHECK. 12 hours0.5 days 0.0714 weeks 0.0164 months SR 3.3 6.2.2 Perform CHANNEL FUNCTIONAL TEST. 92 days RIVER BEND 3.3-59 Amendment No. 81-.113

Secondary Containment and Fuel Building Isolation Instrumentation 3.3.6.2 (continued)

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.6.2.3 Calibrate the trip unit. 92 days SR 3.3.6.2.4 Perform CHANNEL CALIBRATION. 24 months SR 3.3.6.2.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. 24 months RIVER BEND 3.3-60 Amendment No. 81 113, 168

I Secondary Containment and Fuel Building Isolation Instrumentation 3.3.6.2 Table 3.3.6.2-1 (page 1 of 1)

.NI Secondary Containment and Fuel Building Isolation Instrumentation APPLICABLE MODES AND REQUIRED-OTHER CHANNELS SPECIFIED PER TRIP SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM REQUIREMENTS VALUE

1. Reactor Vessel Water 1.2.3 2 SR 3.3.6.2.1 2 -47 inches Level - Low Low. Level 2 SR 3.3.6.2.2 SR 3.3.6.2.3 SR 3.3.6.2.4 SR 3.3.6.2.5

2. DrywEll Pressure -High 1.2.3 2 SR 3.3.6.2.1 s 1.88 psid SR 3.3.6.2.2 SR 3.3.6.2.3 SR 3.3.6.2.4 SR 3.3.6.2.5

3. Fuel Ejilding Ventilatior. (a) 1 SR 3.3.6.2.1 s 2.18 x 103 HCi/seC ExnzLs: Radiation - Hign SR 3.3.6.2.2 (IYM*RE5A) SR 3.3.6.2.4 SR 3.3.6.2.5

4. Fuel Bjilding Ventilation (a) 1 SR 3.3.6.2.1 s 7.05 x 10 4 UCi/cc Exrajs: Radiation -H~gn SR 3.3.6.2.2 (IRV;*RE52) SR 3.3.6.2.4 SR 3.3.6.2.5 E Mar.jl Initiation 1.2.3. 2 SR 3.3.6.2.5 NA (a)

(a: DL;-inc movement of recently irradiated fuel assemblies inthe fuel building for fuel building isolntion.

RIVER BEND 3.3-61 Amendment No. 8H-, 113

Containment Unit Cooler System Instrumentation 3.3.6.3 3.3 INSTRUMENTATION 3.3.6.3 Containment Unit Cooler System Instrumentation LCO 3.3.6.3 The Containment Unit Cooler System instrumentation for each Function in Table 3.3.6.3-1 shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

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

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more channels A.1 Enter the Condition Immediately inoperable. referenced in Table 3.3.6.3-1 for the channel.

B. As required by B.1 Declare associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from Required Action A.1 containment unit discovery of and referenced in cooler subsystem loss of Table 3.3.6.3-1. inoperable. containment unit cooler initiation capability in both trip systems AND B.2 Place channel in 24 hours1 days 0.143 weeks 0.0329 months trip.

(continued)

RIVER BEND 3.3-62 RAmendment No. 81

Containment Unit Cooler System Instrumentation 3.3.6.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. As required by C.1 Declare associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from Required Action A.1 containment unit discovery of and referenced in cooler subsystem loss of Table 3.3.6.3-1. inoperable. containment unit cooler initiation capability in both trip systems AND C.2 Restore channel to 24 hours1 days 0.143 weeks 0.0329 months OPERABLE status.

D. Required Action and D.1 Declare associated Immediately associated Completion containment unit Time of Condition B cooler subsystem or C not met. inoperable.

RIVER BEND 3.3-63 Amendment No. 81

Containment Unit Cooler System Instrumentation 3.3.6.3 SURVEILLANCE REQUIREMENTS

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

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 hours0.25 days 0.0357 weeks 0.00822 months , provided the associated Function maintains containment unit cooler initiation capability.

SURVEILLANCE FREQUENCY SR 3.3.6.3.1 Perform CHANNEL CHECK. 24 hours1 days 0.143 weeks 0.0329 months SR 3.3.6.3.2 Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.6.3.3 Calibrate the trip unit. 92 days SR 3.3.6.3.4 Perform CHANNEL CALIBRATION. 24 months SR 3.3.6.3.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. 24 months RIVER BEND 3.3-64 Amendment No. 8-+, 168

Containment Unit Cooler System Instrumentation 3.3.6.3 Table 3.3.6.3-1 (page 1 of 1)

Containment Unit Cooler System Instrumentation CONDITIONS REQUIRED REFERENCED CHANNELS FROM PER TRIP REQUIRED SURVEILLANCE - ALLOWABLE FUNCTION SYSTEM ACTION A.1 REQUIREMENTS VALUE

1. Drywell Pressure-High 2 B SR 3.3.6.3.1 S 1.88 psid SR 3.3.6.3.2 SR 3.3.6.3.3 SR 3.3.6.3.4 SR 3.3.6.3.5

2. Containment-to-AnnuLus 3 B SR 3.3.6.3.1 2 -12.29 inches of Differential SR 3.3.6.3.2 water and Pressure - High SR 3.3.6.3.3 S -11.71 inches of SR 3.3.6.3.4 water SR 3.3.6.3.5

3. Reactor Vessel Water 2 B SR 3.3.6.3.1 2 -147 inches Level - Low Low Low, SR 3.3.6.3.2 Level 1 SR 3.3.6.3.3 SR 3.3.6.3.4 SR 3.3.6.3.5

4. System A and System B 1 C SR 3.3.6.3.2 k 555 seconds and Timers SR 3.3.6.3.4 S 645 seconds SR 3.3.6.3.5 RIVER BEND 3.3-65 Amendment No. 81

Relief and LLS Instrumentation 3.3.6.4 3.3 INSTRUMENTATION 3.3.6.4 Relief and Low-Low Set (LLS) Instrumentation LCO 3.3.6.4 Two relief and LLS instrumentation trip systems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One trip system A.1 Restore trip system 7 days inoperable. to OPERABLE status.

OR A.2 Declare associated 7 days relief and LLS valve(s) inoperable.

B. Required Action and B.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months associated Completion Time of Condition A AND not met.

B.2 Be in MODE 4. 36 hours1.5 days 0.214 weeks 0.0493 months OR Two trip systems inoperable.

RIVER BEND 3.3-66 Amendment No. 81

Relief and LLS Instrumentation 3.3.6.4 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 hours0.25 days 0.0357 weeks 0.00822 months , provided the associated Function maintains LLS or relief initiation capability, as applicable.

SURVEILLANCE FREQUENCY SR 3.3.6.4.1 Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.6.4.2 Calibrate the trip unit. 92 days SR 3.3.6.4.3 Perform CHANNEL CALIBRATION. The Allowable 24 months Values shall be:

a. Relief Function Low: 1133 +/- 15 psig Medium: 1143 +/- 15 psig High: 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 SR 3.3.6.4.4 Perform LOGIC SYSTEM FUNCTIONAL TEST. 24 months RIVER BEND 3.3-67 Amendment No. 81114,168

CRFA System Instrumentation 3.3.7.1 3.3 INSTRUMENTATION 3.3.7.1 Control Room Fresh Air (CRFA) System Instrumentation LCO 3.3.7.1 The CRFA System instrumentation for each Function in Table 3.3.7.1-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.7.1-1.

ACTIONS

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

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Enter the Condition Immediately channels inoperable. referenced in Table 3.3.7.1-1 for the channel.

B. As required by B.1 Declare associated I hour from Required Action A.1 CRFA subsystem discovery of and referenced in inoperable. loss of CRFA Table 3.3.7.1-1. initiation capability in both trip systems AND B.2 Place channel in 24 hours1 days 0.143 weeks 0.0329 months trip.

(continued)

RIVER BEND 3.3-68 Amendment No. 81

CRFA System Instrumentation 3.3.7.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. As required by C.1 Declare associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from Required Action A.1 CRFA subsystem discovery of and referenced in inoperable. loss of CRFA Table 3.3.7.1-1. initiation capability in both trip systems AND C.2 Place channel in 12 hours0.5 days 0.0714 weeks 0.0164 months trip.

D. As required by D.1 Declare associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from Required Action A.1 CRFA subsystem discovery of and referenced in inoperable. loss of CRFA Table 3.3.7.1-1. initiation capability in both trip systems AND D.2 Place channel in 6 hours0.25 days 0.0357 weeks 0.00822 months trip.

E. Required Action and E.1 Place the associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated Completion CRFA subsystem in I' Time of Condition B, emergency mode.

C, or D not met.

OR E.2 Declare associated CRFA subsystem 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months

- :;inoperable.

__i RIVER BEND 3.3-69 Amendment No. 8O-,95 AUG 2 6 1997

CRFA System Instrumentation 3.3.7.1 SURVEILLANCE REQUIREMENTS

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

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 hours0.25 days 0.0357 weeks 0.00822 months provided the associated Function maintains CRFA initiation capability.

SURVEILLANCE FREQUENCY SR 3.3.7.1.1 Perform CHANNEL CHECK. 12 hours0.5 days 0.0714 weeks 0.0164 months SR 3.3.7.1.2 Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.7.1.3 Calibrate the trip units. 92 days SR 3.3.7.1.4 Perform CHANNEL CALIBRATION. 24 months SR 3.3.7.1.5 Perform LOGIC SYSTEM FUNCTIONAL TEST. 24 months RIVER BEND 3.3-70 Amendment No. M, 168

CRFA System Instrumentation 3.3.7.1 Table 3.3.7.1-1 (page 1 of 1)

Control Room Fresh Air System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION A.1 REQUIREMENTS VALUE Reactor Vesset Water Level - 1.2.3 2 B SR 3.3.7.1.1 2:47 inches Low Low. Level 2 SR 3.3.7.1.2 SR 3.3.7.1.3 SR 3.3.7.1A SR 3.3.7.1.5

2. Drywell Pressure -High 1.2.3 2 C SR 3.3.7.1.1 5 1.88 psid SR 3.3.7.1.2 SR 3.3.7.1.3 SR 3.3.7.14 SR 3.3.7.1.5

3. Control Room Local Intake 1.2.3 1 D SR 3.3.7.1.1 s 0.97 x 105 Ventilation Radiation Monitors (a).(b) SR 3.3.7.1.2 pCi/cc SR 3.3.7.1.4 SR 3.3.7.1.5 (a) During operations with a potential for draining the reactor vessel.

(b) During movement of recently irradiated fuel assemblies in the primary containment or fuel building.

RIVER BEND 3.3-71 Amendment No. 84 5 44, 132

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

APPLICABILITY: MODES 1, 2, and 3, When the associated diesel generator (DG) is required to be OPERABLE by LCO 3.8.2, "AC Sources-Shutdown."

ACTIONS

NOTE-----------------------------6-------

Separate Condition entry is allowed for each channel.

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

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

Time not met.

RIVER BEND 3.3-72 Amendment No. 81

LOP Instrumentation 3.3.8.1 SURVEILLANCE REQUIREMENTS

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 hours0.0833 days 0.0119 weeks 0.00274 months provided the associated Function maintains DG initiation capability.

SURVEILLANCE FREQUENCY SR 3.3.8.1.1 Perform CHANNEL CHECK. 12 hours0.5 days 0.0714 weeks 0.0164 months SR 3.3.8.1.2 Perform CHANNEL FUNCTIONAL TEST. 31 days SR 3.3.8.1.3 Perform CHANNEL CALIBRATION. 24 months SR 3.3.8.1.4 Perform LOGIC SYSTEM FUNCTIONAL TEST. 24 months RIVER BEND 3.3-73 Amendment No. 81 168, 179

LOP Instrumentation 3.3.8.1 Table 3.3.8.1-1 (page 1 of 1)

Loss of Power Instrumentation REQUIRED CHANNELS PER SURVEILLANCE ALLOWABLE FUNCTION DIVISION REQUIREMENTS VALUE

1. Divisions 1 and 2 - 4.16 kV Emergency Bus Undervoltage

a. Loss of Voltage - 4.16 kV basis 3 SR 3.3.8.1.1 2. 3005 V and,; 3302 V SR 3.3.8.1.2 SR 3.3.8.1.3 SR 3.3.8.1.4

b. Loss of Voltage - Time Delay SR 3.3.8.1.3 2. 2.67 seconds and SR 3.3.8.1.4 ,; 3.33 seconds

c. Degraded Voltage - 4.16 kV basis 3 SR 3.3.8.1.1 " 3689.0 V and,; 3735.2 V SR 3.3.81.2 SR 3.3.8.1.3 SR 3.3.8.1.4

d. Degraded Voltage - Time Delay. No SR 3.3.8.1.3 2. 46.59 seconds and LOCA SR 3.3.8.1.4 ,; 57.07 seconds

e. Degraded Voltage - Time Delay, SR 3.3.B.1.3 2. 4.5 seconds and LOCA SR 3.3.B.1.4 ,; 5.7 seconds

2. Division 3 - 4.16 kV Emergency Bus Undervoltage

a. Loss of Voltage - 4.16 kV basis 2 SR 3.3.B.1.1 " 3019 V and $ 3325 V SR 3.3.B.1.3 SR 3.3.8.1.4

b. Loss of Voltage Time Delay 2 SR 3.3.8.1.3 " 2.67 seconds and SR 3.3.B.1.4 s 3.33 seconds

c. Degraded Voltage - 4.16 kV basis 2 SR 3.3.8.1.1 " 3674.0 V and s 3721.2 V SR 3.3.6.1.2 SR 3.3.8.1.3 SR 3.3.6.1.4

d. Degraded Voltage - Time Delay, No 2 SR 3.3.8.1.3 ;;, 44.7 seconds and LOCA SR 3.3.8.1.4 ,; 54.62 seconds

e. Degraded Voltage - Time Delay, 2 SR 3.3.8.1.2 ,,4.5 seconds and LOCA SR 3.3.8.1.3 ,; 5.7 seconds SR 3.3.8.1.4 RIVER BEND 3,3-74 Amendment No. 8195128147151,179

RPS Electric Power Monitoring 3.3.8.2 3.3 INSTRUMENTATION 3.3.8.2 Reactor Protection System (RPS) Electric Power Monitoring LCO 3.3.8.2 Two RPS electric power monitoring assemblies shall be OPERABLE for each inservice RPS motor generator set or alternate power supply.

APPLICABILITY: MODES 1, 2, and 3, MODES 4 and 5 with any control rod withdrawn from a core cell containing one or more fuel assemblies.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or both inservice A.1 Remove associated 72 hours3 days 0.429 weeks 0.0986 months power supplies with one inservice power electric power supply(s) from service.

monitoring assembly inoperable.

B. One or both inservice B.1 Remove associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months power supplies with both inservice power electric power supply(s) from service.

monitoring assemblies inoperable.

C. Required Action and C.1 ---------N 0 TE------------

associated Completion LCO 3.0.4.a is not Time of Condition A or B applicable when not met in MODE 1, 2, entering MODE 3.

or 3. -----------------------------

Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months (continued)

RIVER BEND 3.3-75 Amendment No. 34- 185

RPS Electric Power Monitoring 3.3.8.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Initiate action to Immediately associated Completion fully insert all Time of Condition A or insertable control B not met in MODE 4 rods in core cells or 5 with any control containing one or rod withdrawn from a more fuel assemblies.

core cell containing one or more fuel assemblies.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.8.2.1 ------------------NOTE-------------------

Only required to be performed prior to entering MODE 2 or 3 from MODE 4, when in MODE 4 for > 24 hours1 days 0.143 weeks 0.0329 months .

Perform CHANNEL FUNCTIONAL TEST. 184 days (continued)

RIVER BEND 3.3-76 Amendment No. 81

RPS Electric Power Monitoring 3.3.8.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.8.2.2 Perform CHANNEL CALIBRATION. The Allowable 24 months Values shall be:

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 SR 3.3.8.2.3 Perform a system functional test. 24 months RIVER BEND 3.3-77 Amendment No. 84, 168

Recirculation Loops Operating 3.4.1 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.1 Recirculation Loops Operating LCO 3.4.1 A. Two recirculation loops shall be in operation with matched flows.

OR B. One recirculation loop shall be in operation with:

1. THERMAL POWER

77.6% RTP;

2. Total core flow within limits;

3. LCO 3.2.1,"AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR)," single loop operation limits specified in the COLR;

4. LCO 3.2.2,"MINIMUM CRITICAL POWER RATIO (MCPR),"

single loop operation limits specified in the COLR; and

5. LCO 3.3.1.1, "Reactor Protection System (RPS)

Instrumentation," Function 2.b (Average Power Range Monitors Flow Biased Simulated Thermal Power- High), Allowable Value for single loop operation as specified in the COLR.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Recirculation loop jet pump A.1 Shutdown one recirculation 2 hours0.0833 days 0.0119 weeks 0.00274 months flow mismatch not within loop.

limits.

B. THERMAL POWER B.1 Reduce THERMAL POWER 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months

> 77.6% RTP during single to

77.6% RTP. I loop operation.

(continued)

RIVER BEND 3.4-1 Amendment No. 84, X,,406 444,129 JAN 3 20

Recirculation Loops Operating 3.4.1 CONDITION REQUIRED ACTION COMPLETION TIME C. Requirements B.3. B.4. C.1 Satisfy the requirements of 24 hours1 days 0.143 weeks 0.0329 months or B.5 of the LCO not the LCO.

met.

D. Required actions and D.1 Be in Mode 3. 12 hours0.5 days 0.0714 weeks 0.0164 months associated completion times of conditions A.

B. or C not met.

OR No recirculation loops in operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.1.1 ----------------- NOTE-----------------

Not required to be performed until 24 hours1 days 0.143 weeks 0.0329 months after both recirculation loops are in operation.

Verify recirculation loop jet pump flow mismatch with both recirculation loops in 24 hours1 days 0.143 weeks 0.0329 months operation is:

a. s 10% of rated core flow when operating at

< 70% of rated core flow; and

b.

5% of rated core flow when operating at 2 70% of rated core flow.

RIVER BEND 3.4-2 Amendment No. (E 97 106

,MAY 0 I 33 Otavngos( 6W4# 4l4 aZ S

- -

Recirculation Loops Operating 3.4.1 This Page Left Intentionally Blank.

RIVER BEND 3.4-3 Amendment No. C4 9- 106 MJAY 0 5 ;Y90

-s<Lhol bt Pa ecu&aatw2&7

- - -

Recirculation Loops Operating 3.4.1 This Page Left Intentionally Blank.

RIVER BEND 3.4-4 Amendment No. em 106

__ oe-W -tt 6 6-c- -qq

Recirculation Loops Operating 3.4.1 This Page Left Intentionally Blank.

RIVER BEND 3.4-5 Amendment No. G8 106

-. .- ___ Qg__! b5-6o-qq

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

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 COMPLETION TIME A. One or two required FCVs A.1 Lock up the FCV. 4 hours0.167 days 0.0238 weeks 0.00548 months inoperable.

B. Required Action and B.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months associated Completion Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.2.1 Verify each FCV fails "as is" on loss of hydraulic 24 months pressure at the hydraulic unit.

(continued)

RIVER BEND 3.4-6 Amendment No.~, 168

FCVs 3.4.2

- SURVEILLANCE FREQUENCY SR 3.4.2.2 Verify average rate of each FCV movement is: 24 months

a. :0:; 11 % of stroke per second for opening; and

b. :0:; 11 % of stroke per second for closing.

RIVER BEND 3.4-7 Amendment No. 84, 168

Jet Pumps 3.4.3 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.3 Jet Pumps LCO 3.4.3 All jet pumps shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more jet pumps A.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months inoperable.

RIVER BEND 3.4-8 Amendment No. 81

w7e: Fu-.s

_ . 4 .

SURVEIhLANTCE REtJR:PEMENTS SURVEILLANCE FREQUENCY SR 3.4.3.i -------------------NOTES-------------------

1. Not required to be performed until 4 hours0.167 days 0.0238 weeks 0.00548 months after associated recirculation loop is in operation.

2. Not required to be performed until I 24 hours1 days 0.143 weeks 0.0329 months after > 23.8% RTP.

Verify at least two of the following criteria 24 hours1 days 0.143 weeks 0.0329 months (a. b. and c) are satisfied for each operating recirculation loop:

a. Recirculation loop drive flow versus flow control valve position differs by s 10%

from established patterns.

t Recirculation loop drive flow versus total core flow differs by s 10% from established patterns.

c. Each Jet pump diffuser to lower plenum differential pressure differs by 5 20%.

from established patterns, or each jet pump flow differs by s 10% from established patterns.

(

R2WER BEND 3.4-9 Amendment No. 83. 114 OCT 06 2000

S/RVs 3.4.4 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.4 Safety/Relief Valves (S/RVs)

LCO 3.4.4 The safety function of five S/RVs shall be OPERABLE, AND The relief function of four additional S/RVs shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months S/RVs inoperable.

AND A.2 Be in MODE 4. 36 hours1.5 days 0.214 weeks 0.0493 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.4.1 Verify the safety function lift setpoints of the required In accordance with S/RVs are as follows: the Inservice Testing Program Number of Setpoint S/RVs (Psia) 7 1195 +36,-60 5 1205 +36,-60 4 1210 +36,-60 (continued)

RIVER BEND 3.4-10 Amendment No. 81,1-09114, 130 FEB 1 3 mW

S/RVs 3.4.4 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.4.2 ------------------------------NOTE------------------------------

Valve actuation may be excluded.

Verify each required relief function S/RV actuates on 24 months an actual or simulated automatic initiation signal.

SR 3.4.4.3 ------------------------------NOTE------------------------------

Not required to be performed until 12 hours0.5 days 0.0714 weeks 0.0164 months after reactor steam pressure and flow are adequate to perform the test.

Verify each required SIR V relief mode actuator In accordance with strokes when manually actuated. the Inservice Testing Program on a STAGGERED TEST BASIS for each valve solenoid RIVER BEND 3.4-11 Amendment No. 81 130,168

RCS Operational LEAKAGE 3.4.5 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.5 RCS Operational LEAKAGE LCO 3.4.5 RCS operational LEAKAGE shall be limited to:

a. No pressure boundary LEAKAGE;

b. 5 5 gpm unidentified LEAKAGE;

c. s 30 gpm total LEAKAGE averaged over the previous 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months period; and

d. r 2 gpm increase in unidentified LEAKAGE within the previous 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months period in MODE 1.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Unidentified LEAKAGE A.1 Reduce LEAKAGE to 4 hours0.167 days 0.0238 weeks 0.00548 months not within limit. within limits.

OR Total LEAKAGE not within limit.

B. Unidentified LEAKAGE B.1 Verify source of 4 hours0.167 days 0.0238 weeks 0.00548 months increase not within unidentified LEAKAGE limit. increase is not service sensitive type 304, type 316 austenitic stainless steel, or other intergranular stress corrosion cracking susceptible material.

(continued)

RIVER BEND 3.4-12 Amendment No. 81

RCS Operational LEAKAGE 3.4.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be-in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months associated Completion Time of Condition A AND or B not met.

C.2 Be in MODE 4. 36 hours1.5 days 0.214 weeks 0.0493 months OR Pressure boundary LEAKAGE exists.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.5.1 Verify RCS unidentified LEAKAGE, total 12 hours0.5 days 0.0714 weeks 0.0164 months LEAKAGE, and unidentified LEAKAGE increase are within limits.

RIVER BEND 3.4-13 Amendment No. 81

RCS PIV Leakage 3.4.6 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.6 RCS Pressure Isolation Valve (PIV) Leakage LCO 3.4.6 The leakage from each RCS PIV shall be within limit.

APPLICABILITY: MODES 1 and 2, MODE 3, except valves in the residual heat removal (RHR) shutdown cooling flow path when in, or during the transition to or from, the shutdown cooling mode of operation.

ACTIONS

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

1. Separate Condition entry is allowed for each flow path.

2. Enter applicable Conditions and Required Actions for systems made inoperable by PIVs.

(continued)

RIVER BEND 3.4-14 Amendment No. 81

RCS PIV Leakage 3.4.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more flow paths A.1 -------- NOTE---------

with leakage from one Each check valve used or more RCS PIVs not to satisfy Required within limit. Action A.1 and Required Action A.2 shall have been verified to meet SR 3.4.6.1.

Isolate the high 4 hours0.167 days 0.0238 weeks 0.00548 months pressure portion of the affected system from the low pressure portion by use of one closed manual, deactivated automatic, or check valve.

AND A.2 Isolate the high 72 hours3 days 0.429 weeks 0.0986 months pressure portion of the affected system from the low pressure portion by use of a second closed manual, deactivated automatic, or check valve.

B. Required Action and B.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months associated Completion Time not met. AND B.2 Be in MODE 4. 36 hours1.5 days 0.214 weeks 0.0493 months RIVER BEND 3.4-15 Amendment No. 81

..- - i.4

3. 4 . t

-su E: L LA :E EQUITrEMEN7S _ _ _

SURVEILLANCE FREQUENCY SR 3.4 oI NOTE--------------------

Only required to be performed in MODES 1 and 2.

Verify equivalent leakage of each RCS PIV is s 0.5 gpm per nominal inch of valve size up to In accordance a maximum of 5 gpm. at an RCS pressure with Inservice 2 1040 psig and s 1070 psig. Testing Program RjV-R BENC 3.4-16 Amendment No. Bz-.114 OCT 0 6 2000

RCS Leakage Detection Instrumentation 3.4.7 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.7 RCS Leakage Detection Instrumentation LCO 3.4.7 The following RCS leakage detection instrumentation shall be OPERABLE:

a. Drywell and pedestal floor drain sump monitoring systems;

b. One channel of either drywell atmospheric particulate or atmospheric gaseous monitoring system; and

c. Drywell air cooler condensate flow rate monitoring system.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Drywell or pedestal floor A.1 Restore drywell and 30 days drain sump monitoring pedestal floor drain sump system inoperable. monitoring systems to OPERABLE status.

B. Required drywell B.1 Analyze grab samples of Once per atmospheric monitoring drywell atmosphere. 24 hours1 days 0.143 weeks 0.0329 months system inoperable.

(continued)

RIVER BEND 3.4-17 Amendment No. 81, 156

RCS Leakage Detection Instrumentation 3.4.7 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Drywell air cooler -----------------N OTE ------------.-

condensate flow rate Not applicable when the required monitoring system drywell atmospheric monitoring inoperable. system is inoperable.

...------

C:1 Perform SR 3.4.7.1. Once per 8 hours0.333 days 0.0476 weeks 0.011 months

NOTE------ D.1 Analyze grab samples of Once per 12 hours0.5 days 0.0714 weeks 0.0164 months Only applicable when the the drywell atmosphere.

drywell atmospheric gaseous AND monitoring system is the only OPERABLE monitor. D.2 Monitor RCS leakage by

__ _-_ _----

-_.... ..........-------_.. ........ administrative means.

Once per 12 hours0.5 days 0.0714 weeks 0.0164 months D. Drywell floor drain sump AND monitoring system D.3.1 Restore drywell floor drain 7 days inoperable. sump monitoring system to AND OPERABLE status.

Drywell air cooler OR condensate flow rate D.3.2 Restore drywell air cooler 7 days monitoring system condensate flow rate inoperable. monitoring system to OPERABLE status.

E. Required drywell E.1 Restore required drywell 30 days atmospheric monitoring atmospheric monitoring system inoperable. system to OPERABLE status.

AND OR Drywell air cooler condensate flow rate E.2 Restore drywell air cooler 30 days monitoring system condensate flow rate inoperable. monitoring system to OPERABLE status.

F. Required Action and F.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months associated Completion Time of Condition A. B. C. AND D. or E not met.

F.2 Be in MODE 4. 36 hours1.5 days 0.214 weeks 0.0493 months G. All required leakage G.1 Enter LCO 3.0.3. Immediately detection systems inoperable.

RIVER BEND 3.4-18 Amendment No. 81 1ae. 172

RCS Leakage Detection Instrumentation 3.4.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.7.1 Perform CHANNEL CHECK of required drywell 12 hours0.5 days 0.0714 weeks 0.0164 months atmospheric monitoring system.

SR 3.4.7.2 Perform CHANNEL FUNCTIONAL TEST of required 31 days leakage detection instrumentation.

SR 3.4.7.3 Perform CHANNEL CALIBRATION of required 24 months leakage detection instrumentation.

RIVER BEND 3.4-19 Amendment No. 8-+, 168

RCS Specific Activity 3.4.8 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.8 RCS Specific Activity LCO 3.4.8 The DOSE EQUIVALENT I-131 specific activity of the reactor coolant shall be d 0.2 PCi/gm.

APPLICABILITY: MODE 1, MODES 2 and 3 with any main steam line not isolated.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Reactor coolant specific -------------------NOTE-----------------

activity > 0.2 PCi/gm and LCO 3.0.4.c is applicable.

d 4.0 PCi/gm DOSE --------------------------------------------

EQUIVALENT I -131.

A.1 Determine DOSE Once per 4 hours0.167 days 0.0238 weeks 0.00548 months EQUIVALENT I - 131.

AND A.2 Restore DOSE 48 hours2 days 0.286 weeks 0.0658 months EQUIVALENT I -131 to within limits.

B. Required Action and B.1 Determine DOSE Once per 4 hours0.167 days 0.0238 weeks 0.00548 months associated Completion EQUIVALENT I - 131.

Time of Condition A not met. AND OR B.2.1 Isolate all main steam 12 hours0.5 days 0.0714 weeks 0.0164 months lines.

Reactor coolant specific activity > 4.0 PCi/gm OR DOSE EQUIVALENT I - 131. B.2.2.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months AND B.2.2.2 Be in MODE 4. 36 hours1.5 days 0.214 weeks 0.0493 months RIVER BEND 3.4-20 Amendment No. 81, 156

RCS Specific Activity 3.4.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.8.1 -------------------NOTE ------------------

Only required to be performed in MODE 1.

Verify reactor coolant DOSE 7 days EQUIVALENT I-131 specific activity is

. 0.2 pCi/gm.

RIVER BEND 3.4-21 Amendment No. 81

RHR Shutdown Cooling System - Hot Shutdown 3.4.9 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.9 Residual Heat Removal (RHR) Shutdown Cooling SystemHot Shutdown LCO 3.4.9 Two RHR shutdown cooling subsystems shall be OPERABLE, and, with no recirculation pump in operation, at least one RHR shutdown cooling subsystem shall be in operation.

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

1. Both RHR shutdown cooling subsystems and recirculation pumps may be removed from operation for up to 2 hours0.0833 days 0.0119 weeks 0.00274 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period.

2. One RHR shutdown cooling subsystem may be inoperable for up to 2 hours0.0833 days 0.0119 weeks 0.00274 months for performance of Surveillances.

APPLICABILITY: MODE 3 with reactor steam dome pressure less than the RHR cut in permissive pressure.

ACTIONS

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

Separate Condition entry is allowed for each RHR shutdown cooling subsystem.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or two RHR shutdown A.1 Initiate action to restore Immediately cooling subsystems RHR shutdown cooling inoperable. subsystem(s) to OPERABLE status.

AND (continued)

RIVER BEND 3.4-22 Amendment No. 81, 156

RHR Shutdown Cooling System-Hot Shutdown 3.4.9 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2 Verify an alternate 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months method of decay heat removal is available for each inoperable RHR shutdown cooling subsystem.

AND A.3 Be in MODE 4. 24 hours1 days 0.143 weeks 0.0329 months B. No RHR shutdown B.1 Initiate action to Immediately cooling subsystem in restore one RHR operation. shutdown cooling subsystem or one AND recirculation pump to operation.

No recirculation pump in operation. AND B.2 Verify reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from coolant circulation discovery of no by an alternate reactor coolant method. circulation AND Once per 12 hours0.5 days 0.0714 weeks 0.0164 months thereafter AND B.3 Monitor reactor Once per hour coolant temperature and pressure.

RIVER BEND 3.4-23 Amendment No. 81

RHR Shutdown Cooling System - Hot Shutdown 3.4.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.9.1 ----------------------------N0 TE---------------------------------

Not required to be met until 2 hours0.0833 days 0.0119 weeks 0.00274 months after reactor steam dome pressure is less than the RHR cut in permissive pressure.

Verify one RHR shutdown cooling subsystem or 12 hours0.5 days 0.0714 weeks 0.0164 months recirculation pump is operating.

SR 3.4.9.2 ----------------------------N 0 TE---------------------------------

Not required to be performed until 12 hours0.5 days 0.0714 weeks 0.0164 months after reactor steam dome pressure is less than the RHR cut in permissive pressure.

Verify RHR shutdown cooling subsystem locations 31 days susceptible to gas accumulation are sufficiently filled with water.

RIVER BEND 3.4-24 Amendment No. ~. 188

RHR Shutdown Cooling System-Cold Shutdown 3.4.10 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.10 Residual Heat Removal (RHR) Shutdown Cooling System-Cold Shutdown LCO 3.4.10 Two RHR shutdown cooling subsystems shall be OPERABLE, and, with no recirculation pump in operation, at least one RHR shutdown cooling subsystem shall be in operation.

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

1. Both RHR shutdown cooling subsystems and recirculation pumps may be removed from operation for up to 2 hours0.0833 days 0.0119 weeks 0.00274 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period.

2. One RHR shutdown cooling subsystem may be inoperable for up to 2 hours0.0833 days 0.0119 weeks 0.00274 months for the performance of Surveillances.

3. Both RHR shutdown cooling subsystems and recirculation pumps may be removed from operation during RCS inservice leak and hydrostatic testing.

APPLICABILITY: MODE 4.

ACTIONS

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

Separate Condition entry is allowed for each RHR shutdown cooling subsystem.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or two RHR A.1 Verify an alternate 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months shutdown cooling method of decay heat subsystems inoperable. removal is available AND for each inoperable RHR shutdown cooling Once per subsystem. 24 hours1 days 0.143 weeks 0.0329 months thereafter (continued)

RIVER BEND 3.4-25 Amendment No. 81

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

CONDITION REQUIRED ACTION COMPELETION TIME B. No RHR shutdown cooling B.1 Verify reactor coolant 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from discovery subsystem in operation. circulating by an of no reactor coolant alternate method. circulation No recirculation pump in operation. Once per 12 hours0.5 days 0.0714 weeks 0.0164 months thereafter B.2 Monitor reactor coolant Once per hour temperature and pressure.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.10.1 Verify one RHR shutdown cooling subsystem or 12 hours0.5 days 0.0714 weeks 0.0164 months recirculation pump is operating.

SR 3.4.10.2 Verify RHR shutdown cooling subsystem locations 31 days susceptible to gas accumulation are sufficiently filled with water.

RIVER BEND 3.4-26 Amendment No. g..t, 188

RCS P/T Limits 3.4.11 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.11 RCS Pressure and Temperature (P/T) Limits LCO 3.4.11 RCS pressure, RCS temperature, RCS heatup and cooldown rates, and the recirculation loop temperature requirements shall be maintained within limits.

APPLICABILITY: At all times.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. ---- NOTE--------- A.1 Restore parameter(s) 30 minutes Required Action A.2 to within limits.

shall be completed if this Condition is AND entered.

A.2 Determine RCS is 72 hours3 days 0.429 weeks 0.0986 months acceptable for Requirements of the continued operation.

LCO not met in MODES 1, 2, and 3.

B. Required Action and B.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months associated Completion Time of Condition A AND not met.

B.2 Be in MODE 4. 36 hours1.5 days 0.214 weeks 0.0493 months (continued)

RIVER BEND 3.4-27 Amendment No. 81

RCS P/T Limits 3.4.11 AZT.",,,NS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C -------- NOT- C.1 Initiate action to restore Immediately Required Action C.2 parameter(s) to within shall be completed if limits.

this Condition is entered. AND

.C.2 Determine RCS is acceptable Prior to entering Requirements of the LCO for operation. MODE 2 or 3 not met itr. other than MODES 1. 2. ana 3.

S J :LANCE REQUIREMENTS _

SURVEILLANCE FREQUENCY S; 3.4.11.1 - -- ------ NOTE--------------------

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

Verify: 30 minutes

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

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

C. 0F RCS heatup and cooldown rates are c.._20 I in any one hour period for inservice leak and hydrostatic testing limits (continued)

R.IVE; BEND 3.4-28 Amendment No. &j.114 OCT e 6 203 0

RCS P/T Limits 3.4.11 SUrV-E!LANCE REGUIREMENTS (continued)

T SURVEILLANCE FREQUENCY S; < 4.11i.2 - ------------------NOTE--------------------

Only required to be met during control rod withdrawal for the purpose of achieving criticality.

Verify RCS pressure and RCS temperature are Once within within the core critical limits specified in 15 minutes prior Figure 3.4.11-1. to control rod withdrawal for the purpose of achieving criticality as , 5 , 3 ------ NOTE----------------

Only required to be met in MODES 1. 2. 3. and 4 with reactor steam dome pressure 2 25 psig .

during recirculation pump start.

Verify the difference between the bottom head Once within coolant temperature and the reactor pressure 15 minutes prior vessel (RPV) coolant temperature is s 100 0F. to each startup of a recirculation pump St 3.Z.1i.4 ------------------ NOTE--------------------

Only required to be met in MODES 1. 2. 3. and 4 during recirculation pump start.

Verify the difference between the reactor Once within coolant temperature in the recirculation loop 15 minutes prior to be started and the RPV coolant temperature to each startup is s 500F. of a recirculation pump (continued) f,VEZ BEND 3.4-29 Amendment No. 8-.. 114 OCT 06 2&JO

RCS P/T Limits 3.4.11 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.11.5 -------------------NOTE--------------------

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

Verify reactor vessel flange and head 30 minutes flange temperatures are > 70'F.

SR 3.4.11.6 -------------------NOTE--------------------

Not required to be performed until 30 minutes after RCS temperature 5 800 F in MODE 4.

Verify reactor vessel flange and head 30 minutes flange temperatures are ; 70F.

SR 3.4.11.7 -------------------NOTE--------------------

Not required to be performed until 12 hours0.5 days 0.0714 weeks 0.0164 months after RCS temperature s 100OF in MODE 4.

Verify reactor vessel flange and head 12 hours0.5 days 0.0714 weeks 0.0164 months flange temperatures are z 700F.

(continued)

RIVER BEND 3.4-30 Amendment No. 81

RCS P/T Limits 3.4.11 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY 4.

SR 3.4.11.8 ------------------- NOTE----------------

Only required to be met in single loop

-operation during increases in THERMAL POWER or recirculation loop flow with the

.-recirculation loop flow in the operating loop 5 50% of rated recirculation loop flow I .or THERMAL POWER < 30% of RTP.

___________________________________________

Verify the difference between the bottom Once within head coolant temperature and the RPV 15 minutes coolant temperature is < 100*F. prior to an increase in THERMAL POWER or an increase in loop flow t

SR 3.4.11.9 -------------------NOTE--------------------

Only required to be met in single loop operation during increases in THERMAL POWER or recirculation loop flow with the recirculation loop flow in the operating loop

50% of rated recirculation loop I flow, or THERMAL POWER < 30% of RTP, and the idle recirculation loop not isolated from the RPV.

___________________________________________

Verify the difference between the reactor Once within coolant temperature in the recirculation 15 minutes loop not in operation and the RPV coolant prior to an temperature is < 500F. increase in THERMAL POWER or an increase in loop flow RIVER BEND 3.4-31 Amendment No. &I,95 AUG 2 6 1997

RCS P/T Limits 3.4.11 A B C 1400 INITIAL RTndt VALUES ARE

-50°F FOR BELTLINE 10°F FOR UPPER VESSEL, AND 19°F FOR BOTTOM HEAD 1200 ----- i- --- - - BELTLINE CURVES ADJUSTED AS SHOWN:

EFPY SHIFT (°F)

/ 32 152 HEATUP/COOLDOWN

~io1000 _ / RATE OF COOLANT 20°F/HR FOR CURVE A.

-

o / i U/ 100'F/HR FOR CURVES B&C o A. B, C - LIMITING CURVE 800 - - .l A - PRESSURE TEST WITH

>i / . FUEL IN THE VESSEL B - NON-NUCLEAR

t HEATUP/COOLDOWN Ui CORE NOT CRITICAL Z 600 ..

C - NUCLEAR E .HEATUP/COOLDOWN

.CORE CRITICAL U.'

A LIMITING U. 400.B LIMITING IL .C LIMITING

13UESIG. C ARE VALID UP TO

. . / l32 EFPY 200 _ .-.-- _ _ . .

0 0 25 50 75 100 125 150 175 200 225 250 MINIMUM REACTOR VESSEL METAL TEMPERATURE (OF)

Figure 3.4.11-1 (Page 1 of 1)

Minimum Temperature Required vs. RCS Pressure RIVER BEND 3.4-32 Amendment 84-. 99.144-. I o&

Reactor Steam Dome Pressure 3.4.12 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.12 Reactor Steam Dome Pressure I LCO 3.4.12 The reactor steam dome pressure shall be 5 1075 psig.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Reactor steam dome A.1 Restore reactor steam dome 15 minutes pressure not within pressure to within limit.

limit.

B. Required Action and B.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months associated Completion Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.12.1 Verify reactor steam dome pressure is 12 hours0.5 days 0.0714 weeks 0.0164 months I s 1075 psig.

RIVER BEND 3.4-33 Amendment No. 8F-.114 OCT 0 6 2Q00

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

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

ACTIONS

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

LCO 3.0.4.b is not applicable to HPCS.

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

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

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

RIVER BEND 3.5-1 Amendment No. 81, 156

ECCS- Operating 3.5.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Two ECCS injection C.1 Restore one ECCS 72 hours3 days 0.429 weeks 0.0986 months subsystems inoperable. injection/spray subsystem to OR OPERABLE status.

One ECCS injection and one ECCS spray subsystem inoperable.

D. Required Action and D.1 ----------N 0 TE-----------

associated Completion LCO 3.0.4.a is not Time of Condition A, B, applicable when or C not met. entering MODE 3.

Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months E. One ADS valve inoperable. E.1 Restore ADS valve to 14 days OPERABLE status.

F. One ADS valve F.1 Restore ADS valve to 72 hours3 days 0.429 weeks 0.0986 months inoperable. OPERABLE status.

AND OR One low pressure EGGS F.2 Restore low pressure 72 hours3 days 0.429 weeks 0.0986 months injection/spray EGGS injection/spray subsystem inoperable subsystem to OPERABLE status.

(continued) I RIVER BEND 3.5-2 Amendment No. 8-.i 185

ECCS- Operating 3.5.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME G. Two or more ADS valves G.1 ----------NOTE-----------

inoperable. LCO 3.0.4.a is not applicable when entering MODE 3.

Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months Required Action and associated Completion Time of Condition E or F not met.

(continued) I RIVER BEND 3.5-2a Amendment No. ~ 185

ECCS- Operating 3.5.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME H. HPCS and Low Pressure H.1 Enter LCO 3.0.3. Immediately Core Spray (LPCS)

Systems inoperable.

OR Three or more ECCS injection/spray subsystems inoperable.

OR HPCS System and one or more ADS valves inoperable.

OR Two or more ECCS injection/spray subsystems and one or more ADS valves inoperable.

RIVER BEND 3.5-3 Amendment No. 84 185

ECCS - Operating 3.5.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.1 Verify, for each ECCS injection/spray subsystem, 31 days locations susceptible to gas accumulation are sufficiently filled with water.

SR 3.5.1.2 -----------------------------N 0 TE--------------------------------

1. Low pressure coolant injection (LPCI) subsystems may be considered OPERABLE during alignment and operation for decay heat removal with reactor steam dome pressure less than the residual heat removal cut in permissive pressure in MODE 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, 31 days power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.

SR 3.5.1.3 Verify ADS accumulator supply pressure is 31 days 2 131 psig.

SR 3.5.1.4 Verify each ECCS pump develops the specified flow In accordance with rate with the specified pump differential pressure. the lnservice Testing Program PUMP DIFFERENTIAL SYSTEM FLOW RATE PRESSURE LPCS 2 5010 gpm 2 282 psid LPCI 2 5050 gpm 2 102 psid HPCS 2 5010 gpm 2 415 psid (continued)

RIVER BEND 3.5-4 Amendment No. 84, 188

ECCS - Operating 3.5.1 SURVEILLANCE REQUIREMENTS (continued)

SU RVE ILLANCE FREQUENCY SR 3.5.1.5 -----------------------------NOTE-------------------------------

Vessel injection/spray may be excluded.

Verify each ECCS injection/spray subsystem 24 months actuates on an actual or simulated automatic initiation signal.

SR 3.5.1.6 -------------------------------NOTE-----------------------------

Valve actuation may be excluded.

Verify the ADS actuates on an actual or simulated 24 months automatic initiation signal.

SR 3.5.1.7 ------------------------------NOTE------------------------------

Not required to be performed until 12 hours0.5 days 0.0714 weeks 0.0164 months after reactor steam pressure and flow are adequate to perform the test.

Verify each ADS valve relief mode actuator strokes In accordance with when manually actuated. the Inservice Testing Program on a STAGGERED TEST BASIS for each valve solenoid SR 3.5.1.8 -------------------------------NOTE-----------------------------

ECCS actuation instrumentation is excluded.

Verify the ECCS RESPONSE TIME for each ECCS 24 months injection/spray subsystem is within limits.

RIVER BEND 3.5-5 Amendment No. B1 130,168

-

ECCS-Shutdown 3.5.2 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING KU (RCIC) SYSTEM 3.5.2 ECCS-Shutdown LCO 3.5.2 Two ECCS injection/spray subsystems shall be OPERABLE.

APPLICABILITY: MODE 4, MODE 5 except with the upper containment fuel pool gate opened and water level 2 23 ft over the top of the reactor pressure vessel flange.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required ECCS A.1 Restore required ECCS 4 hours0.167 days 0.0238 weeks 0.00548 months injection/spray injection/spray subsystem inoperable. subsystem to OPERABLE status.

B. Required Action and B.1 Initiate action to Immediately associated Completion suspend operations Time of Condition A with a potential for not met. draining the reactor vessel (OPDRVs).

C. Two required ECCS C.1 Initiate action to Immediately injection/spray suspend OPDRVs.

subsystems inoperable.

AND C.2 Restore one ECCS 4 hours0.167 days 0.0238 weeks 0.00548 months injection/spray subsystem to OPERABLE status.

(continued)

RIVER BEND 3.5-6 Amendment No. 81

ECCS-Shutdown 3.5.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action C.2 D.1 Initiate action to Immediately and associated restore primary Completion Time not containment to met. OPERABLE status.

AND D.2 Initiate action to Immediately isolate required primary containment penetration flow paths.

AND D.3 --------- NOTE--------

Entry and exit is permissible under administrative control.

Initiate action to Immediately close one door in each primary containment air lock.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify, for each required low pressure ECCS 12 hours0.5 days 0.0714 weeks 0.0164 months injection/spray subsystem, the suppression pool water level is 2 13 ft 3 inches.

(continued)

RIVER BEND 3.5-7 Amendment No. 81

ECCS- Shutdown 3.5.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.2.2 Verify, for the required High Pressure Core Spray 12 hours0.5 days 0.0714 weeks 0.0164 months (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.

SR 3.5.2.3 Verify, for each required ECCS injection/spray 31 days subsystem, locations susceptible to gas accumulation are sufficiently filled with water.

SR 3.5.2.4 -------------------------------N0 TE------------------------------

1. One low pressure coolant injection (LPCI) subsystem may be considered OPERABLE 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 each required ECCS injection/spray subsystem 31 days 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.

(continued)

RIVER BEND 3.5-8 Amendment No. 84, 188

ECCS- Shutdown 3.5.2 SURVEILLANCE FREQUENCY SR 3.5.2.5 Verify each required ECCS pump develops the In accordance with specified flow rate with the specified pump differential the Inservice pressure. Testing Program PUMP DIFFERENTIAL SYSTEM FLOW RATE PRESSURE LPCS ~ 5010 gpm ~ 282 psid LPCI ~ 5050 gpm ~ 102 psid HPCS ~ 5010 gpm ~ 415 psid SR 3.5.2.6 -----------------------------NaTE-------------------------------

Vessel injection/spray may be excluded.

Verify each required ECCS injection/spray subsystem 24 months actuates on an actual or simulated automatic initiation signal.

RIVER BEND 3.5-9 Amendment No. 8-+, 168

RCIC System 3.5.3 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.3 RCIC System LCO 3.5.3 The RCIC System shall be OPERABLE.

APPLICABILITY: MODE 1, MODES 2 and 3 with reactor steam dome pressure > 150 psig.

ACTIONS

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

LCO 3.0.4.b is not applicable to RCIC.

CONDITION REQUIRED ACTION COMPLETION TIME A. RCIC System inoperable. A.1 Verify by administrative 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months means High Pressure Core Spray System is OPERABLE.

AND A.2 Restore RCIC System 14 days to OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months associated Completion Time not met. AND B.2 Reduce reactor steam 36 hours1.5 days 0.214 weeks 0.0493 months dome pressure to d 150 psig.

RIVER BEND 3.5-10 Amendment No. 81, 156

RCIC System 3.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.3.1 Verify the RCIC System locations susceptible to gas 31 days accumulation are sufficiently filled with water.

SR 3.5.3.2 -----------------------------N 0 TE-------------------------------- 31 days 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.

SR 3.5.3.3 -----------------------------N 0 TE--------------------------------

Not required to be performed until 12 hours0.5 days 0.0714 weeks 0.0164 months after reactor steam pressure and flow are adequate to perform the test.

Verify, with RCIC steam supply pressure :s; 1075 psig 92 days and~ 920 psig, the RCIC pump can develop a flow rate ~ 600 gpm against a system head corresponding to reactor pressure.

SR 3.5.3.4 -----------------------------N 0 TE--------------------------------

Not required to be performed until 12 hours0.5 days 0.0714 weeks 0.0164 months after reactor steam pressure and flow are adequate to perform the test.

Verify, with RCIC steam supply pressure :s; 165 psig 24 months and ~ 150 psig, the RCIC pump can develop a flow rate ~ 600 gpm against a system head corresponding to reactor pressure.

(continued)

RIVER BEND 3.5-11 Amendment No. 81114168, 188

RCIC System 3.5.3 SURVEILLANCE FREQUENCY SR 3.5.3.5 ------------------------------NOTE------------------------------

Vessel injection may be excluded.

Verify the RCIC System actuates on an actual or 24 months simulated automatic initiation signal.

RIVER BEND 3.5-12 Amendment No. g.+, 168

Primary Containment-Operating 3.6.1.1 3.6 CONTAINMENT SYSTEMS 3.6.1.1 Primary Containment-Operating LCO 3.6.1.1 Primary containment shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Primary containment A.1 Restore primary 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. containment to OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months associated Completion Time not met. AND B.2 Be in MODE 4. 36 hours1.5 days 0.214 weeks 0.0493 months RIVER BEND 3.6-1 Amendment No. 81

Primary Containment-Operating 3.6.1.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.1.1 Perform required visual examinations and In accordance leakage rate testing except for primary with the containment air lock testing, in Primary accordance with the Primary Containment Containment Leakage Rate Testing Program. Leakage Rate Testing Program RIVER BEND 3.6-2 Amendment No. 84,84 DEC ' 9 1995

Primary Containment Air Locks 3.6.1.2 3.6 CONTAINMENT SYSTEMS 3.6.1.2 Primary Containment Air Locks LCO 3.6.1.2 Two primary containment air locks shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3, I During movement of recently irradiated fuel assemblies in the primary containment, I During operations with a potential for draining the reactor vessel (OPDRVs).

ACTIONS N

1. Entry and exit is permissible to perform repairs of the affected air lock components.

2. Separate Condition entry is allowed for each air lock.

3. Enter applicable Conditions and Required Actions of LCO 3.6.1.1, "Primary Containment-Operating," when air lock leakage results in exceeding overall containment leakage rate acceptance criteria in MODES 1, 2, and 3.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more primary ------------NOTES------------

containment air locks 1. Required Actions A.1, with one primary A.2, and A.3 are not containment air lock applicable if both doors door inoperable. in the same air lock are inoperable and Condition C is entered.

2. Entry and exit is permissible for 7 days under administrative controls if both air locks are inoperable.

___________________(continued (continued)

RIVER BEND 3.6-3 Amendment No. 8&,85 JAN I1 6nt

Primary Containment Air Locks 3.6.1.2 ACTIONS -

CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.1 Verify the OPERABLE 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months door is closed in the affected air lock.

AND A.2 Lock the OPERABLE 24 hours1 days 0.143 weeks 0.0329 months door closed in the affected air lock.

AND A.3 -------- NOTE---------

Air lock doors in high radiation areas may be verified locked closed by administrative means.

Verify the OPERABLE Once per 31 days door is locked closed in the affected air lock.

B. One or more primary ------------NOTES------------

containment air locks 1. Required Actions B.1, with primary B.2, and B.3 are not containment air lock applicable if both doors interlock mechanism in the same air lock are inoperable. inoperable and Condition C is entered.

2. Entry and exit is permissible under the control of a dedicated individual.

(continued)

RIVER BEND 3.6-4 Amendment No. 81

Primary Containment Air Locks 3.6.1.2 ACTIONS CONDITION 'REQUIRED ACTION COMPLETION TIME B. (continued) B.1 Verify an OPERABLE 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months door is closed in the affected air lock.

AND B.2 Lock an OPERABLE door 24 hours1 days 0.143 weeks 0.0329 months closed in the affected air lock.

AND B.3 --- NOTE---------

Air lock doors in high radiation areas may be verified locked closed by administrative means.

Verify an OPERABLE Once per 31 days door is locked closed in the affected air lock.

C. One or more primary C.1 Initiate action to Immediately containment air locks evaluate primary inoperable for reasons containment overall other than Condition A leakage rate per or B. LCO 3.6.1.1, using current air lock test results.

AND C.2 Verify a door is 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months closed in the affected air lock.

AND (continued)

RIVER BEND 3.6-5 Amendment No. 81

Primary Containment Air Locks 3.6.1.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. (continued) C.3 Restore air lock to 24 hours1 days 0.143 weeks 0.0329 months OPERABLE status.

D. Required Action and D.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months associated Completion Time of Condition A, AND B, or C not met in MODE 1, 2, or 3. D.2 Be in MODE 4. 36 hours1.5 days 0.214 weeks 0.0493 months E. Required Action and E.1 Suspend movement of Immediately associated Completion recently irradiated Time of Condition A, fuel assemblies in B, or C not met during the primary movement of recently containment.

irradiated fuel assemblies in the AND K)I primary containment OPDRVs. E.3 Initiate action to Immediately suspend OPDRVs.

Immediately RIVER BEND 3.6-6 Amendment No. 81,85

-JANi Il ~ 3l;

-

Primary Containment Air Locks 3.6.1.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.2.1 NOTES

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 In accordance with leakage rate testing in accordance with the Primary the Primary Containment Leakage Rate Testing Program. Containment Leakage Rate Testing Program I SIR 3.6.1.2.2 Verify primary containment air lock seal 7 days air flask pressure is 2 90 psig.

SR 3.6.1.2.3 NOTE Only required to be performed upon entry or exit through the primary containment air lock.

Verify only one door in the primary containment air 184 days lock can be opened at a time.

(continued)

RIVER BEND 3.6-7 Amendment No. S4 84, 132

Primary Containment Air Locks 3.6.1.2 SURVEILLANCE REQUIREMENTS (continued SURVEILLANCE FREQUENCY SR 3.6.1.2.4 Verify, from an initial pressure of 24 months 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 hours1 days 0.143 weeks 0.0329 months .

RIVER BEND 3.6-8 Amendment No. 81 132, 168

PCIVs 3.6.1.3 3.6 CONTAINMENT SYSTEMS 3.6.1.3 Primary Containment Isolation Valves (PCIVs)

LCO 3.6.1.3 Each PCIV shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3, MODES 4 and 5 for RHR Shutdown Cooling System suction from the reactor vessel isolation valves when associated isolation instrumentation is required to be OPERABLE per LCO 3.3.6.1, "Primary Containment and Drywell Isolation Instrumentation," Function 5.b.

ACTIONS

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

1. Penetration flow paths may be unisolated intermittently under administrative controls.

2. Separate Condition entry is allowed for each penetration flow path.

3. Enter applicable Conditions and Required Actions for systems made inoperable by PCIVs.

4. Enter applicable Conditions and Required Actions of LCO 3.6.1.1, 'Primary Containment-Operating," when PCIV leakage results in exceeding overall containment leakage rate acceptance criteria, in MODES 1, 2, and 3.

(continued)

RIVER BEND 3.6-9 Amendment No. 81

-

PCIVs 3.6.1.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 Isolate the affected 4 hours0.167 days 0.0238 weeks 0.00548 months except penetration flow paths penetration flow path for main steam with one PCIV by the use of at line inoperable except due least one closed and to leakage not within de-activated AND limit. automatic valve, closed manual valve, 8 hours0.333 days 0.0476 weeks 0.011 months for main blind flange, or steam line check valve with flow through the valve secured.

AND (continued)

RIVER BEND 3 .6-10 Amendment No. 81

PCIVs 3.6.1.3 ACTIONS CONDITION I REQUIRED ACTION I COMPLETION TIME A. (continued) A.2 --------NOTE---------

Isolation devices in high radiation areas may be verified by use of administrative means.

Verify the affected Once per 31 days penetration flow path for isolation is isolated. devices outside primary containment, drywell, and steam tunnel AND Prior to entering MODE 2 or 3 from MODE 4, if not performed within the previous 92 days, for isolation devices inside primary containment, drywell, or steam tunnel B. One or more B.1 Isolate the affected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months penetration flow paths penetration flow path with two PCIVs by use of at least inoperable except due one closed and to leakage not within de-activated limit. automatic valve, closed manual valve, or blind flange.

(continued)

RIVER BEND 3 .6-11 Amendment No. 81

PCIVs 3.6.1.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One or more C.1 Restore leakage rate 4 hours0.167 days 0.0238 weeks 0.00548 months penetration flow paths to within limit.

with leakage rate not within limit except for purge valve leakage.

(continued)

RIVER BEND 3 .6-12 Amendment No. 81

PCIVs 3.6.1.3 ACTIONS (continued)

CONDITION I REQUIRED ACTION I COMPLETION TIME D. One or more D.1 Isolate the affected 24 hours1 days 0.143 weeks 0.0329 months penetration flow paths penetration flow path with one or more by use of at least primary containment one closed and purge valves not de-activated within purge valve automatic valve, leakage limits. closed manual valve, or blind flange.

AND D.2 -------- NOTE---------

Isolation devices in high radiation areas may be verified by use of administrative means.

Verify the affected Once per 31 days penetration flow path for isolation is isolated. devices outside primary containment AND Prior to entering MODE 2 or 3 from MODE 4 if not performed within the previous 92 days for isolation devices inside primary containment AND (continued)

RIVER BEND 3. 6-13 Amendment No. 81

PCIVs 3.6.1.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. (continued) D.3 Perform SR 3.6.1.3.5 Once per for the resilient 92 days seal purge valves closed to comply with Required Action D.1.

E. Required Action and E.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months associated Completion Time of Condition A, AND B, C, or D not met in MODE 1, 2, or 3. E.2 Be in MODE 4. 36 hours1.5 days 0.214 weeks 0.0493 months F. Required Action and F.1 Initiate action to Immediately associated Completion suspend OPDRVs.

Time of Condition A, B, C, or D not met for OR PCIV(s) required to be OPERABLE during MODE 4 F.2 Initiate action to Immediately or 5. restore valve(s) to OPERABLE status.

RIVER BEND 3.6-14 Amendment No. 81

- -

PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.3.1 - ------------- NOTES------------------

1. Only required to be met in MODES 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 OPERABLE. In addition only one SGT subsystem may be operating in the primary containment purge flow path.

Verify each 36 inch primary containment 31 days purge valve is closed.

(continued)

RIVER BEND 3.6-15 Amendment No. 81

PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

.5.

SR 3.6.1.3.2 ------------------NOTES------------------

1. Only required to be met in MODES 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 31 days manual valve and blind flange that is located outside primary containment. drywell. and steam tunnel and is required to be closed during accident conditions is closed.

L I (continued)

RIVER BEND 3.6-16 Amendment No. 6+. 116

PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.1.3.3 ------------------NOTES------------------

1. Only required to be met in MODES 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.

4. Not required to be met for the Inclined Fuel Transfer System (IFTS) penetration when the associated primary containment blind flange is removed, provided that the fuel building spent fuel storage pool water level is maintained greater than 23 feet above the top of the fuel.

and the IFTS transfer tube drain valve remains closed. The IFTS transfer tube drain valve may be opened under administrative controls. Removal of the IFTS Blind Flange shall not exceed 60 days per operating cycle while in Modes 1. 2. or 3.

Verify each primary containment isolation Prior to manual valve and blind flange that is located entering MODE 2 inside primary containment. drywell. or steam or 3 from tunnel and is required to be closed during MODE 4. if not accident conditions is closed. performed within the previous 92 days (continued)

RIVER BEND 3.6-16a Amendment No. 8., 6, 117

PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.1.3.4 Verify the isolation time of each power operated In accordance and each automatic PCIV, except MSIVs, is within with the Inservice limits. Testing Program SR 3.6.1.3.5 ----------------------------NOTE----------------------------

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

Perform leakage rate testing for each primary In accordance with containment purge valve with resilient seals. the Primary Containment Leakage Rate Testing Program SR 3.6.1.3.6 Verify the isolation time of each MSIV is In accordance with the Inservice

~ 3 seconds and ~ 5 seconds. Testing Program SR 3.6.1.3.7 Verify each automatic PCIV actuates to the 24 months isolation position on an actual or simulated isolation signal.

(continued)

RIVER BEND 3.6-17 Amendment No. 81 152,168

PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.1.3.8 Verify in-leakage rate of:::; 340 scfh for each of the 24 months following valve groups when tested at 11.5 psid for MS-PLCS valves.

a. Division I MS-PLCS valves

b. Division II MS-PLCS valves SR 3.6.1.3.9 ----------------------------NOT E----------------------------

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

Verify the combined leakage rate for all secondary In accordance with containment bypass leakage paths is :::; 580,000 the Primary cc/hr when pressurized to ~ Pa . Containment Leakage Rate Testing Program (continued)

RIVER BEND 3.6-18 Amendment No. 81 84 98 132, 168

PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.1.3.10 ------------------ NOTE-------

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

Verify the total leakage rate through the valves In accordance I served by each division of MS-PLCS is < 150 scfh with the Primary per division when tested at 2 Pa. Containment Leakage Rate Testing Program SR 3.6.1.3.11 -NOTE----_ _ _--a Only required to be met in MODES 1, 2, and 3.

Verify combined leakage rate through In accordance with hydrostatically tested lines that penetrate the the Primary primary containment is within limits. Containment Leakage Rate Testing Program (continued)

RIVER BEND 3.6-1 9 Amendment No. 84 84 132, 143

PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.1.3.12 Deleted. I RIVER BEND 3.6-20 Amendment No. g 84, 132

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 >- -0.3 psig and s 0.3 psig.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS _

CONDITION REQUIRED ACTION COMPLETION TIME A. Primary containment A.1 Restore primary 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months pressure not within containment pressure limits. to within limits.

B. Required Action and B.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months associated Completion Time not met. AND B.2 Be in MODE 4. 36 hours1.5 days 0.214 weeks 0.0493 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.4.1 Verify primary containment pressure is 12 hours0.5 days 0.0714 weeks 0.0164 months within limits.

RIVER BEND 3.6-21 Amendment No. 81

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 - 900F.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Primary containment A.1 Restore primary 8 hours0.333 days 0.0476 weeks 0.011 months average air containment average temperature not within air temperature to limit. within limit.

B. Required Action and B.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months associated Completion Time not met. AND B.2 Be in MODE 4. 36 hours1.5 days 0.214 weeks 0.0493 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.5.1 Verify primary containment average air 24 hours1 days 0.143 weeks 0.0329 months temperature is within limit.

RIVER BEND 3.6-22 Amendment No. 81

LLS Valves 3.6.1.6 3.6 CONTAINMENT SYSTEMS 3.6.1.6 Low-Low Set (LLS) Valves LCO 3.6.1.6 The LLS function of five safety/relief valves shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One LLS valve inoperable. A.1 Restore LLS valve to 14 days OPERABLE status.

B. Required Action and B.1 ----------N 0 TE-----------

associated Completion LCO 3.0.4.a is not Time of Condition A not applicable when met. entering MODE 3.

Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months C. Two or more LLS valves C.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months Inoperable.

AND C.2 Be in MODE 4. 36 hours1.5 days 0.214 weeks 0.0493 months RIVER BEND 3.6-23 Amendment No. 84 185

LLS Valves 3.6.1.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.6.1 ---------------------------NOTE-----------------------------

Not required to be performed until 12 hours0.5 days 0.0714 weeks 0.0164 months after reactor steam pressure and flow are adequate to perform the test.

Verify each LLS valve relief mode actuator strokes In accordance with when manually actuated. the Inservice Testing Program on a STAGGERED TEST BASIS for each valve solenoid SR 3.6.1.6.2 ----------------------------NOTE----------------------------

Valve actuation may be excluded.

Verify the LLS System actuates on an actual or 24 months simulated automatic initiation signal.

RIVER BEND 3.6-24 Amendment No. 81 130,168

Primary Containment Unit Coolers 3.6.1.7 3.6 CONTAINMENT SYSTEMS 3.6.1.7 Primary Containment Unit Coolers LCO 3.6.1.7 Two primary containment unit coolers shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required primary A.1 Restore required 7 days containment unit cooler primary containment inoperable. unit cooler to OPERABLE status.

B. Two required primary B.1 Restore one required 8 hours0.333 days 0.0476 weeks 0.011 months containment unit coolers primary containment inoperable. unit cooler to OPERABLE status.

C. Required Action and C.1 ----------N 0 TE-----------

associated Completion LCO 3.0.4.a is not Time not met. applicable when entering MODE 3.

Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months RIVER BEND 3.6-25 Amendment No. 8--i 185

Primary Containment Unit Coolers 3.6.1.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.7.1 Verify each required primary containment unit 31 days 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.

SR 3.6.1.7.2 Verify each required primary containment unit 92 days cooler develops a flow rate of 2 50,000 cfm on recirculation flow through the unit cooler.

SR 3.6.1.7.3 Verify each required primary containment unit 24 months cooler actuates throughout its emergency operating sequence on an actual or simulated automatic initiation signal.

RIVER BEND 3.6-26 Amendment No. 8-+, 168

PVLCS 3.6.1.8 3.6 CONTAINMENT SYSTEMS 3.6.1.8 Deleted RIVER BEND 3.6-27 Amendment No. 84-,98 AUG 2 6 1997

- -

PVLCS 3.6.1.8 THIS PAGE INTENTIONALLY LEFT BLANK RIVER BEND 3.6-28 Amendment No. 8+,98 CUG - 6 J397

MS-PL CS 3.6.1.9 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 COMPLETION TIME A. One MS-PLCS subsystem A.1 Restore MS-PLCS 30 days inoperable. subsystem to OPERABLE status.

B. Two MS-PLCS B.1 Restore one MS-PLCS 7 days 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. 12 hours0.5 days 0.0714 weeks 0.0164 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.9.1 Verify air pressure in each associated PVLCS 24 hours1 days 0.143 weeks 0.0329 months subsystem is 2'. 101 psig.

(continued)

.RIVER BEND 3.6-29 Amendment No. ~ 185

MS-PLCS 3.6.1.9 SURVEILLANCE REQUIREMENTS (continued)

__________ S_U_RV_E_I_L_LA_N_c_E ---+~REQUENCY SR 3.6.1.9.2 Operate each PVLCS compressor ~ 15 minutes. 131 days 1,------------

SR 3.6.1.9.3 Perform a system functional test of each MS-PLCS 124 months subsystem.

I RIVER BEND 3.6-30 Amendment No. 8+, 168

Primary Containment-Shutdown 3.6.1.10 3.6 CONTAINMENT SYSTEMS 3.6.1.10 Primary Containment-Shutdown LCO 3.6.1.10 Primary containment shall be OPERABLE.

I APPLICABILITY: During movement of recently irradiated fuel assemblies in the primary containment.

I During operations with a potential for draining the reactor vessel (OPDRVs).

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Primary containment A.1 Suspend movement of Immediately I inoperable. recently irradiated fuel assemblies in the primary containment.

AND I

I A.2 Initiate action to suspend Immediately OPDRVs.

RIVER BEND 3.6-31 Amendment No. 8+- 119

Primary Containment-Shutdown 3.6.1.10 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.10.1 ------------------NOTE: ------------------

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, 31 days required to be closed during accident conditions, is closed.

RIVER BEND 3.6-32 Amendment No. 81

Suppression Pool Average Temperature 3.6.2.1 3.6 CONTAINMENT SYSTEMS 3.6.2.1 Suppression Pool Average Temperature LCO 3.6.2.1 Suppression pool average temperature shall be:

a. < 100I F when THERMAL POWER is > 1% RTP and no testing that adds heat to the suppression pool is being performed;

b. S 105OF when THERMAL POWER is > 1% RTP and testing that adds heat to the suppression pool is being performed; and

c. < 110OF when THERMAL POWER is < 1% RTP.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Suppression pool A.1 Verify suppression Once per hour average temperature pool average

> 100OF but - 110 0F. temperature is s 1100F.

AND AND THERMAL POWER > 1%

RTP. A.2 Restore suppression 24 hours1 days 0.143 weeks 0.0329 months pool average AND temperature to

< 1000 F.

Not performing testing that adds heat to the suppression pool.

B. Required Action and B.1 Reduce THERMAL POWER 12 hours0.5 days 0.0714 weeks 0.0164 months associated Completion to < 1% RTP.

Time of Condition A not met.

(continued)

RIVER BEND 3.6-33 Amendment No. 81

Suppression Pool Average Temperature 3.6.2.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Suppression pool C.1 Suspend all testing Immediately average temperature that adds heat to the,

> 105 0F. suppression pool.

AND THERMAL POWER > 1%

RTP.

AND Performing testing that adds heat to the suppression pool.

D. Suppression pool D.1 Place the reactor Immediately average temperature mode switch in the

> 110 0F but s 120 0F. shutdown position.

AND D.2 Verify suppression Once per pool average 30 minutes temperature is s 1200F.

AND D.3 Be in MODE 4. 36 hours1.5 days 0.214 weeks 0.0493 months E. Suppression pool E.1 Depressurize the 12 hours0.5 days 0.0714 weeks 0.0164 months average temperature reactor vessel to

> 120 0F. < 200 psig.

AND E.2 Be in MODE 4. 36 hours1.5 days 0.214 weeks 0.0493 months RIVER BEND 3.6-34 Amendment No. 81

Suppression Pool Average Temperature 3.6.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY 4.

SR 3.6.2.1.1 Verify suppression pool average 24 hours1 days 0.143 weeks 0.0329 months temperature is within the applicable limits. AND 5 minutes when performing testing that adds heat to the suppression pool RIVER BEND 3.6-35 Amendment No. 81

Suppression Pool Water Level 3.6.2.2 3.6 CONTAINMENT SYSTEMS 3.6.2.2 Suppression Pool Water Level LCO 3.6.2.2 Suppression pool water level shall be 2 19 ft 6 inches and

< 20 ft 0 inches.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Suppression pool water A.1 Restore suppression 2 hours0.0833 days 0.0119 weeks 0.00274 months level not within pool water level to limits. within limits.

B. Required Action and B.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months associated Completion Time not met. AND B.2 Be in MODE 4. 36 hours1.5 days 0.214 weeks 0.0493 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.2.1 Verify suppression pool water level is 24 hours1 days 0.143 weeks 0.0329 months within limits.

RIVER BEND 3.6-36 Amendment No. 81

RHR Suppression Pool Cooling 3.6.2.3 3.6 CONTAINMENT SYSTEMS 3.6.2.3 Residual Heat Removal (RHR) Suppression Pool Cooling LCO 3.6.2.3 Two RHR suppression pool cooling subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One RHR suppression A.1 Restore RHR 7 days pool cooling subsystem suppression pool cooling inoperable. subsystem to OPERABLE status.

B. Required Action and B.1 ----------N 0 TE-----------

associated Completion LCO 3.0.4.a is not Time of Condition A not applicable when met. entering MODE 3.

Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months C. Two RHR suppression C.1 Restore one RHR 8 hours0.333 days 0.0476 weeks 0.011 months pool cooling subsystems suppression pool cooling inoperable. subsystem to OPERABLE status.

D. Required Action and D.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months associated Completion Time of Condition C not AND met.

D.2 Be in MODE 4. 36 hours1.5 days 0.214 weeks 0.0493 months RIVER BEND 3.6-37 Amendment No. 3-i, ~. 185

RHR Suppression Pool Cooling 3.6.2.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.3.1 Verify each RHR suppression pool cooling 31 days 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.

SR 3.6.2.3.2 Verify RHR suppression pool cooling subsystem 31 days locations susceptible to gas accumulation are sufficiently filled with water.

SR 3.6.2.3.3 Verify each RHR pump develops a flow rate In accordance

~ 5050 gpm through the associated heat with the lnservice exchangers to the suppression pool. Testing Program RIVER BEND 3.6-38 Amendment No. 84-, 188

3.6 CONTAINMENT SYSTEMS 3.6.3.1 DELETED RIVER BEND 3.6-39 Amendment No. 84,142

THIS PAGE INTENTIONALLY LEFT BLANK I RIVER BEND 3.640 Amendment No. 84,142

Primary Containment and Drywell Hydrogen Igniters 3.6.3.2 3.6 CONTAINMENT SYSTEMS 3.6.3.2 Primary Containment and Drywell Hydrogen Igniters LCO 3.6.3.2 Two divisions of primary containment and drywell hydrogen igniters shall be OPERABLE, each with > 90% of the associated igniter assemblies OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One primary containment A.1 Restore primary 30 days and drywell hydrogen containment and drywell igniter division inoperable. hydrogen igniter division to OPERABLE status.

B. Two primary containment B.1 Verify by administrative 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and drywell hydrogen means that the igniter divisions inoperable. hydrogen control function is maintained.

AND B.2 Restore one primary 7 days containment and drywell hydrogen igniter division to OPERABLE status.

(continued)

RIVER BEND 3.6-41 Amendment No. 81, 156

Primary Containment and Drywell Hydrogen Igniters 3.6.3.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months associated Completion Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.2.1 Energize each primary containment and drywell 184 days hydrogen igniter division and perform current versus voltage measurements to verify required igniters in service.

SR 3.6.3.2.2 -----------------------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 drywell 92 days hydrogen igniter division and perform current versus voltage measurements to verify required igniters in service.

SR 3.6.3.2.3 Verify each required igniter in inaccessible areas 24 months develops sufficient current draw for a ~ 1700°F surface temperature.

(continued)

RIVER BEND 3.6-42 Amendment No. %4-, 168

Primary Containment and Drywell Hydrogen Igniters 3.6.3.2 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.6.3.2.4 Verify each required igniter in accessible areas 24 months develops a surface temperature of ~ 1700°F.

RIVER BEND 3.6-43 Amendment No. M, 168

Primary Containment/Drywell Hydrogen Mixing System 3.6.3.3 3.6 CONTAINMENT SYSTEMS 3.6.3.3 Primary Containment/Drywell Hydrogen Mixing System LCO 3.6.3.3 Two primary containment/drywell hydrogen mixing subsystems shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One primary A.1 Restore primary 30 days containment/drywell containment/drywell hydrogen mixing hydrogen mixing subsystem inoperable. subsystem to OPERABLE status.

B. Two primary B.1 Verify by administrative 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months containment/drywell means that the hydrogen mixing hydrogen control subsystems inoperable. function is maintained.

AND B.2 Restore one primary 7 days containment/drywell hydrogen mixing subsystem to OPERABLE status.

(continued)

RIVER BEND 3.6-44 Amendment No. 81, 156

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

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months associated Completion Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.3.1 Operate each primary containment/drywell Every COLD hydrogen mixing subsystem for z 15 minutes. SHUTDOWN, if not performed within the previous 92 days.

SR 3.6.3.3.2 Verify each primary containment/drywell hydrogen 24 months mixing subsystem flow rate is z 600 cfm.

RIVER BEND 3.6-45 Amendment No.~, 168

Secondary Containment-Operating 3.6.4.1 3.6 CONTAINMENT SYSTEMS 3.6.4.1 Secondary Containment-Operating 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 hours0.167 days 0.0238 weeks 0.00548 months inoperable. containment to OPERABLE status.

B. Required Action and B.1 ----------N 0 TE-----------

associated Completion LCO 3.0.4.a is not Time not met. applicable when entering MODE 3.

Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.1.1 Verify shield building annulus and auxiliary building 24 hours1 days 0.143 weeks 0.0329 months vacuum is 2'. 3.0 and 2'. 0.0 inch of vacuum water gauge, respectively.

(continued)

RIVER BEND 3.6-46 Amendment No.~.~. 185

Secondary Containment-Operating 3.6.4.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.4.1.2 Verify all secondary containment equipment 31 days hatches are closed and sealed and loop seals filled.

SR 3.6.4.1.3 Verify each secondary containment access door is 31 days closed, except when the access opening is being used for entry and exit.

SR 3.6.4.1.4 Verify each standby gas treatment (SGT) 24 months on subsystem will draw down the shield bUilding a STAGGERED annulus and auxiliary bUilding to ~ 0.5 and TEST BASIS

~ 0.25 inch of vacuum water gauge in ::; 18.5 and

34.5 seconds, respectively.

SR 3.6.4.1.5 Deleted Not Applicable 24 months on a SR 3.6.4.1.6 Verify each SGT sUbsystem can maintain ~ 0.5 STAGGERED and ~ 0.25 inch of vacuum water gauge in the TEST BASIS 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 .

SR 3.6.4.1.7 Deleted Not Applicable RIVER BEND 3.6-47 Amendment No. 81 95 113 132, 168

- .

SCIDs/FBIDs I 3.6.4.2 3.6 CONTAINMENT SYSTEMS 3.6.4.2 Secondary Containment Isolation Dampers (SCIDs) and Fuel Building Isolation I Dampers (FBIDs)

I LCO 3.6.4.2 Each SCID and FBID shall be OPERABLE.

.I APPLICABILITY: MODES 1. 2. and 3 for secondary containment isolation.

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

ACTIONS

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

1. Penetration flow paths may be unisolated intermittently under administrative controls.

2. Separate Condition entry is allowed for each penetration flow path.

3. Enter applicable Conditions and Required Actions for systems made inoperable by I SCIDs or FBIDs.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more penetration A.1 Isolate the affected 8 hours0.333 days 0.0476 weeks 0.011 months flow paths with one SCID penetration flow path I or FBID inoperable. by use of at least one closed and de-activated automatic damper.

closed manual damper.

or blind flange.

AND (continued)

RIVER BEND 3.6-48 Amendment No. 8+.113

I SCIDs/FBIDs 3.6.4.2 CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2 -------- NOTE---------

Isolation devices in high radiation areas may-be verified by use of administrative means.

Verify the affected Once per 31 days penetration flow path is isolated.

B. One or more penetration B.1 Isolate the affected 4 hours0.167 days 0.0238 weeks 0.00548 months flow paths with two penetration flow path SCIDs or two FBIDs by use of at least one inoperable. closed and de-activated automatic damper.

closed manual damper.

or blind flange.

C. Required Action and C.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months associated Completion Time of Condition A or B AND not met for SCIDs in MODE 1. 2. or 3. C.2 Be in MODE 4. 36 hours1.5 days 0.214 weeks 0.0493 months D. Required Action and ------------- NOTE------------

associated Completion LCO 3.0.3 is not applicable.

Time of Condition A or B not met for FBIDs during I movement of recently irradiated fuel D.1 Suspend movement of recently irradiated Immediately assemblies in the fuel fuel assemblies in the building. fuel building.

RIV R BEND 3.6-49 Amendment No. &-. 113

SCIDs/FBIDs 3.6.4.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.2.1 Verify the isolation time of each required power 92 days operated automatic SCID and FBID is within limits.

SR 3.6.4.2.2 Verify each required automatic SCID and FBID 24 months actuates to the isolation position on an actual or simulated automatic isolation signal.

RIVER BEND 3.6-50 Amendment No. 81 95 113, 168

SGT System 3.6.4.3 3.6 CONTAINMENT SYSTEMS 3.6.4.3 Standby Gas Treatment (SGT) System LCO 3.6.4.3 Two SGT subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One SGT subsystem A.1 Verify OPERABLE 4 hours0.167 days 0.0238 weeks 0.00548 months inoperable. SGT subsystem not operating in the primary containment purge flow path.

AND A.2 Restore SGT 7 days subsystem 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 hours0.5 days 0.0714 weeks 0.0164 months C. Two SGT subsystems C.1 ----------NOTE-----------

inoperable in MODE 1, 2, LCO 3.0.4.a is not or 3. applicable when entering MODE 3.

Be in Mode 3. 12 hours0.5 days 0.0714 weeks 0.0164 months RIVER BEND 3.6-51 Amendment No. g.:t. 185

SGT System 3.6.4.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.3.1 Operate each SGT subsystem for~ 15 continuous 31 days minutes.

SR 3.6.4.3.2 Perform required SGT filter testing in accordance In accordance with with the Ventilation Filter Testing Program (VFTP). the VFTP SR 3.6.4.3.3 Verify each SGT subsystem actuates on an actual . 24 months or simulated initiation signal.

SR 3.6.4.3.4 Verify each SGT filter cooling bypass 24 months damper can be opened and the fan started.

RIVER BEND 3.6-52 Amendment No. S+, 4-S8, 183

3.6 CONTAINMENT SYSTEMS 3.6.4.4 Deleted RIVER BEND 3.6-53 Amendment No. 81, 143

THIS PAGE INTENTIONALLY LEFT BLANK I RIVER BEND 3.6-54 Amendment No. 04, 143

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

l APPLICABILITY: During movement of recently irradiated fuel assemblies in the fuel building.

ACTIONS LCO 3.0.3 is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. Fuel building A.1 Suspend movement of Immediately I inoperable. recently irradiated fuel assemblies in the fuel building.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.5.1 Verify fuel building vacuum is 2 0.25 24 hours1 days 0.143 weeks 0.0329 months inch of vacuum water gauge.

SR 3.6.4.5.2 Verify all fuel building equipment hatch 31 days covers are installed.

SR 3.6.4.5.3 Verify each fuel building access door is 31 days closed. except when the access opening is being used for entry and exit.

RIVER BEND 3.6-55 Amendment No. S-. i- 113

- -

3.6 CONTAINMENT SYSTEMS l 3.6.4.6 Deleted RIVER BEND 3.6-56 Amendment No. 8-. 113

- -

THIS PAGE INTENTIONALLY LEFT BLANK RIVER BEND 3.6-57 Amendment No. SF 113

Fuel Building Ventilation System-Fuel Handling 3.6.4.7

. I 3.6 CONTAINMENT SYSTEMS 3.6.4.7 Fuel Building Ventilation System - Fuel Handling LCO 3.6.4.7 Two fuel building ventilation charcoal filtration subsystems shall be OPERABLE and one shall be operating in emergency mode.

I APPLICABILITY: During movement of recently irradiated fuel assemblies in the fuel building.

ACTIONS

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

LCO 3.0.3 is not applicable.

CONDITION REQIRED ACTION COMPLETION TIME A. One fuel building A.1 Restore fuel buildina 7 days ventilation charcoal ventilation charcoal filtration subsystem filtration subsystem to inoperable. OPERABLE status.

B. Required Action and B.1 Suspend movement of Immediately associated Completion recently irradiated Time of Condition A not fuel assemblies in the met. fuel building.

OR Two fuel building ventilation charcoal filtration subsystems inoperable OR One fuel building ventilation charcoal filtration subsystem not in operation.

RIVER BEND 3.6-58 Amendment No. &S-.113

Fuel Building Ventilation System-Fuel Handling 3.6.4.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.7.1 Verify one fuel building ventilation charcoal 12 hours0.5 days 0.0714 weeks 0.0164 months filtration subsystem in operation.

SR 3.6.4.7.2 Operate each fuel building ventilation charcoal 31 days filtration subsystem for~ 15 continuous minutes.

SR 3.6.4.7.3 Perform fuel building ventilation charcoal filtration In accordance with filter testing in accordance with the Ventilation

the VFTP Filter Testing Program (VFTP).

SR 3.6.4.7.4 Verify each fuel building ventilation charcoal 24 m6nths filtration subsystem actuates on an actual or simula~ed initiation signal.

SR 3.6.4.7.5 Verify each fuel building ventilation charcoal 24 months filtration filter cooling bypass damper. can be op~ned and the fan started.

RIVER BEND 3.6-59 Amendment No. 31-, +es, 183

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

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Drywell inoperable. A.1 Restore drywell to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months associated Completion Time not met. AND B.2 Be in MODE 4. 36 hours1.5 days 0.214 weeks 0.0493 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.1.1 Verify personnel door inflatable seal air flask 7 days pressure ~ 75 psig.

SR 3.6.5.1.2 Verify from an initial pressure of 75 psig, the 24 months personnel door inflatable seal pneumatic system pressure does not decay at a rate equivalent to

~ 20.0 psig for a period of 24 hours1 days 0.143 weeks 0.0329 months .

(continued)

RIVER BEND 3.6-60 Amendment No. 31 132, 168

Drywell 3.6.5.1 SURVEILLANCE REQUIREMENTS continued SURVEILLANCE FREQUENCY SR 3.6.5.1.3 Verify bypass leakage is less than or equal to the --------N 0 TE-------

bypass leakage limit. S R 3.0.2 is not applicable for However, during the first unit startup following extensions > 9 bypass leakage testing performed in accordance months with this SR, the acceptance criterion is ~ 10% of the drywell bypass leakage limit.

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 AND 180 months RIVER BEND 3.6-61 Amendment No. 8187144, 191

Drywell 3.6.5.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY Once prior to SR 3.6.5.1.4 Visually inspect the exposed accessible performance of interior and exterior surfaces of the each Type A drywell. test required by SR 3.6.1.1.1 SR 3.6.5.1.5 Verify seal leakage rate when the gap Once within 72 between the door seals is pressurized to hours after k 3 psid. each drywell air lock door closing SR 3.6.5.1.6 Verify drywell air lock leakage by 24 months performing an air lock barrel leakage test at k 3 psid.

l RIVER BEND 3.6-62 Amendment No. 81, 87

-jry2 9 19 6

Drywell Air Lock 3.6.5.2 3.6 CONTAINMENT SYSTEMS 3.6.5.2 Drywell Air Lock LCO 3.6.5.2 The drywell air lock shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

_----------------NOTE ------ -------------------------------

I Entry and exit is permissible to perform repairs of the affected air lock components.

I ______________________________________________________________________________

CONDITION REQUIRED ACTION COMPLETION TIME A. One drywell air lock ------------NOTES------------

door inoperable. 1. Required Actions A.1, A.2, and A.3 are not applicable if both doors in the air lock are inoperable and.

Condition C is entered.

2. Entry and exit is permissible for 7 days under administrative controls.

A.1 Verify the OPERABLE 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months door is closed.

(continued)

I RIVER BEND 3.6-63 Amendment No. 81, 87 IVU 2 9 1996

I Drywell Air Lock 3.6.5.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2 Lock the OPERABLE 24 hours1 days 0.143 weeks 0.0329 months door closed.

A.3 Verify by Once per 31 days administrative means the OPERABLE door is locked closed.

B. Drywell air lock ------------NOTES------------

interlock mechanism 1. Required Actions B.1, inoperable. B.2, and B.3 are not applicable if both doors in the air lock are inoperable and Condition C is entered.

2. Entry and exit is permissible under the control of a dedicated individual.

B.1 Verify an OPERABLE 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months door is closed.

QAN B.2 Lock an OPERABLE door 24 hours1 days 0.143 weeks 0.0329 months closed.

B.3 Verify by Once per 31 days administrative means an OPERABLE door is locked closed.

(continued)

I RIVER BEND 3.6-64 Amendment No. 84, 87

=1JM' 2 9 1996

i Drywell Air Lock 3.6.5.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME I C. Drywell air lock C.1 Verify a door is 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable for reasons closed.

other than Condition A or B. AND C.2 Restore air lock to 24 hours1 days 0.143 weeks 0.0329 months OPERABLE status.

D. Required Action and D.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months associated Completion Time not met. AND D.2 Be in MODE 4. 36 hours1.5 days 0.214 weeks 0.0493 months I RIVER BEND 3.6-65 Amendment No. 81, 87 JiP 2 9 1996

Drywell Air Lock 3.6.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.2.1 Deleted SR 3.6.5.2.2 Verify drywell air lock seal air flask pressure is 7 days

~ 75 psig.

SR 3.6.5.2.3 ---------------------------NOTE-----------------------------

Only required to be performed upon entry into drywell.

Verify only one door in the drywell air lock can be 24 months opened at a time.

SR 3.6.5.2.4 Deleted SR 3.6.5.2.5 Verify, from an initial pressure of 75 psig, the 24 months drywell air lock seal pneumatic system pressure does not decay at a rate equivalent to> 20.0 psig for a period of 24 hours1 days 0.143 weeks 0.0329 months .

RIVER BEND 3.6-66 Amendment No. 81 87 132, 168

Drywell Isolation Valves 3.6.5.3 3.6 CONTAINMENT SYSTEMS 3.6.5.3 Drywell Isolation Valves LCO 3.6.5.3 Each Drywell Isolation Valve shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

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

1. Penetration flow paths, except for the 24 inch purge valve-penetration flow path, may be unisolated intermittently under administrative controls.

2. Separate Condition entry is allowed for each penetration flow path.

3. Enter applicable Conditions and Required Actions for systems made inoperable by Drywell Isolation Valves.

I CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 Isolate the affected 8 hours0.333 days 0.0476 weeks 0.011 months penetration flow paths penetration flow path with one drywell by use of at least isolation valve one closed and inoperable. de-activated automatic valve, closed manual valve, blind flange, or check valve with flow through the valve secured.

(continued)

RIVER BEND 3.6-67 Amendment No. 8&, 87 2 9 j9~q 7AWlr r

Drywell Isolation Valves 3.6.5.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2 --------NOTE---------

Isolation devices in high radiation areas may be verified by use of administrative means.

_____________________

Verify the affected Prior to penetration flow path entering MODE 2 is isolated. or 3 from MODE 4, if not performed within the previous 92 days B. One or more B.1 Isolate the affected 4 hours0.167 days 0.0238 weeks 0.00548 months penetration flow paths penetration flow path with two drywell by use of at least isolation valves one closed and inoperable. de-activated automatic valve, closed manual valve, blind flange, or check valve with flow through the valve secured.

C. One or more Hydrogen C.1 Isolate the affected Immediately Mixing penetration penetration flow path flow paths not within by use of at least the limitations one closed and de-specified in SR activated automatic 3.6.5.3.6 valve, blind flange, or check valve with flow through the valve secured.

D. Required Action and D.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months associated Completion Time not met. AND D.2 Be in MODE 4. 36 hours1.5 days 0.214 weeks 0.0493 months RIVER BEND 3.6-68 Amendment No. 81-9

I 199 5

Drywell Isolation Valves 3.6.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.3.1 Verify each 24 inch drywell purge 31 days isolation valve is sealed closed.

SR 3.6.5.3.2 -----------------NOTE--------------------

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

__________________________________-______

Verify each primary containment/drywell 31 days hydrogen mixing isolation valve is closed.

SR 3.6.5.3.3 ------------------NOTES------------------

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 Prior to valve and blind flange that is required entering MODE 2 to be closed during accident conditions or 3 from is closed. MODE 4, if not performed in the previous 92 days (continued)

RIVER BEND 3.6-69 Amendment No. 81,89 t.,'Jv 1 2 195.

Drywell Isolation Valves 3.6.5.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.5.3.4 Verify the isolation time of each power operated In accordance and each automatic drywell isolation valve is within with the Inservice limits. Testing Program SR 3.6.5.3.5 Verify each automatic drywell isolation valve 24 months actuates to the isolation position on an actual or simulated isolation signal.

SR 3.6.5.3.6 Verify the cumulative time that the primary 31 days containmenVdrywell hydrogen mixing inlet or outlet penetrations are open to be ~ 5 hours0.208 days 0.0298 weeks 0.00685 months per 365 days in Modes 1 and 2, and ~ 90 hours3.75 days 0.536 weeks 0.123 months per 365 days in Mode 3.

RIVER BEND 3.6-70 Amendment No. 8-i--39-, 168

Drywell Pressure 3.6.5.4 3.6 CONTAINMENT SYSTEMS 3.6.5.4 Drywell Pressure LCO 3.6.5.4 Drywell-to-primary containment differential pressure shall be 2 -0.3 psid and s 1.2 psid.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Drywell-to-primary A.1 Restore drywell-to- 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months containment primary containment differential pressure differential pressure not within limits. to within limits.

B. Required Action and B.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months associated Completion Time not met. AND B.2 Be in MODE 4. 36 hours1.5 days 0.214 weeks 0.0493 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.4.1 Verify drywell-to-primary containment 12 hours0.5 days 0.0714 weeks 0.0164 months differential pressure is within limits.

RIVER BEND 3.6-71 Amendment No. 81

Drywell Air Temperature 3.6.5.5 3.6 CONTAINMENT SYSTEMS 3.6.5.5 Drywell Air Temperature LCO 3.6.5.5 Drywell average air temperature shall be - 145 0F.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Drywell average air A.1 Restore drywell 8 hours0.333 days 0.0476 weeks 0.011 months temperature not within average air limit. temperature to within limit.

B. Required Action and B.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months associated Completion Time not met. AND B.2 Be in MODE 4. 36 hours1.5 days 0.214 weeks 0.0493 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.5.1 Verify drywell average air temperature is 24 hours1 days 0.143 weeks 0.0329 months within limit.

RIVER BEND 3.6-72 Amendment No. 81

SSW System and UHS 3.7.1 3.7 PLANT SYSTEMS 3.7.1 Standby Service Water (SSW) System and Ultimate Heat Sink (UHS)

LCO 3.7.1 Two SSW subsystems and the UHS shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One division with one A.1 Restore cooling tower 30 days UHS cooling tower fan fan cell to OPERABLE cell inoperable. status.

B. Both divisions with B.1 Restore one cooling 7 days one UHS cooling tower tower fan cell to fan cell inoperable. OPERABLE status.

C. One division with both C.1 Declare associated Immediately UHS cooling tower fan SSW subsystem cells inoperable. inoperable.

D. UHS basin inoperable. D.1 Restore UHS basin to 72 hours3 days 0.429 weeks 0.0986 months OPERABLE status.

E. One SSW subsystem with E.1 Restore pump to 30 days one pump inoperable. OPERABLE status.

(continued)

RIVER BEND 3.7-1 Amendment No. 81

SSW System and UHS 3.7.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F. Two SSW subsystems F.1 Restore one pump to 7 days with one pump OPERABLE status.

inoperable.

G. One SSW subsystem ------------NOTES------------

inoperable for reasons 1. Enter applicable other than Condition E Conditions and Required or F. Actions of LCO 3.8.1, "AC Sources-Operating,"

for diesel generator made inoperable by SSW.

2. Enter applicable Conditions and Required Actions of LCO 3.4.9, "Residual Heat Removal (RHR) Shutdown Cooling System-Hot Shutdown,"

for RHR shutdown cooling subsystem made inoperable by SSW.

G.1 Restore SSW subsystem 72 hours3 days 0.429 weeks 0.0986 months to OPERABLE status.

(continued)

RIVER BEND 3.7-2 Amendment No. 81

SSW System and UHS 3.7.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME 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. 12 hours0.5 days 0.0714 weeks 0.0164 months I. Required Action and 1.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months associated Completion Time of Condition B, D or AND F not met.

1.2 Be in MODE 4. 36 hours1.5 days 0.214 weeks 0.0493 months OR Both SSW subsystems inoperable for reasons other than Condition F.

OR Three or four UHS cooling tower fan cells inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.1.1 Verify the water level of UHS cooling tower basin is 24 hours1 days 0.143 weeks 0.0329 months

~78%.

SR 3.7.1.2 Verify the average water temperature of UHS is 24 hours1 days 0.143 weeks 0.0329 months

$; 88°F.

SR 3.7.1.3 Operate each cooling tower fan cell for ~ 15 minutes. 31 days (continued)

RIVER BEND 3.7-3 Amendment No. ~ 185

SSW System and UHS 3.7.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.7.1.4 Verify each required SSW subsystem manual, power 31 days 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.

SR 3.7.1.5 Verify each SSW subsystem actuates on an actual or 24 months simulated initiation signal.

RIVER BEND 3.7-4 Amendment No. 3-1-, 168

CRFA System 3.7.2 3.7 PLANT SYSTEM 3.7.2 Control Room Fresh Air (CRFA) System LCO 3.7.2 Two CRFA subsystems shall be OPERABLE.

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

The control room envelope (CRE) boundary may be opened intermittently under administrative control.

APPLICABILITY: MODES 1, 2, and 3, During movement of recently irradiated fuel assemblies in the primary containment, or fuel building.

During operations with a potential for draining the reactor vessel (OPDRVs).

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One CRFA subsystem A.1 Restore CRFA subsystem 7 days inoperable for reasons to OPERABLE status.

other than Condition B.

B. One or more CRFA B.1 Initiate action to implement Immediately subsystems inoperable mitigating actions.

due to inoperable CRE boundary in MODE 1, 2, AND or 3.

B.2 Verify mitigating actions 24 hours1 days 0.143 weeks 0.0329 months ensure CRE occupant exposures to radiological, chemical, and smoke hazards will not exceed limits.

AND B.3 Restore CRE boundary to 90 days OPERABLE status.

(continued)

RIVER BEND 3.7-5 Amendment No. 81 119 132, 154

CRFA System 3.7.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 ----------N 0 TE-----------

Associated Completion LCO 3.0.4.a is not Time of Condition A or B applicable when not met in MODE 1, 2, entering MODE 3.

or 3. -----------------------------

Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months D. Required Action and ------------------N 0 TE------------------

associated Completion LCO 3.0.3 is not applicable.

Time of Condition A not --------------------------------------------

met during movement of recently irradiated fuel D.1 Place OPERABLE Immediately assemblies in the primary CRFA subsystem in containment or fuel emergency mode.

building or during OPDRVs. OR D.2.1 Suspend movement of Immediately recently irradiated fuel assemblies in the primary containment and fuel building.

AND D.2.2 Initiate action to Immediately suspend OPDRVs.

E. Two CRFA subsystems E.1 ----------N 0 TE-----------

inoperable in MODE 1, 2, LCO 3.0.4.a is not or 3 for reasons other than applicable when Condition B. entering MODE 3.

Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months (continued)

RIVER BEND 3.7-6 Amendment No. 81 11 Q 132 154 185

CRFA System 3.7.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F. Two CRFA subsystems F.1 Suspend movement of Immediately inoperable during recently irradiated fuel movement of recently assemblies in *the primary irradiated fuel assemblies containment and fuel in the primary containment building.

or fuel building, or during OPDRVs.

. F.2 Initiate action to suspend Immediately OPDRVs.

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, or during OPDRVs.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.2.1 Operate each CRFA subsystem for::::: 15 continuous 31 days minutes.

SR 3.7.2.2 Perform required CRFA filter testing in accordance In accordance with with the Ventilation Filter Testing Program (VFTP). the VFTP SR 3.7.2.3 Verify each CRFA subsystem actuates on an actual 24 months or simulated initiation signal.

(continued)

RIVER BEND 3.7-7 Amendment No. 81 119 132 154 165 168, 183

CRFA System 3.7.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.7.2.4 Perform required CRE unfiltered air inleakage testing In accordance with in accordance with CRE Habitability Program. the CRE Habitability Program RIVER BEND 3.7-8 Amendment No. 81, 154

Control Room AC System 3.7.3

3. 7 PLANT SYSTEMS 3.7.3 Control Room Air Conditioning (AC) System LCO 3.7.3 Two control room AC subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3, During movement of recently irradiated fuel assemblies in the primary containment or fuel building.

During operations with a potential for draining the reactor vessel (OPDRVs).

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One control room AC A.1 Restore control room AC 30 days subsystem inoperable. subsystem to OPERABLE status.

B. Two control room AC B.1 Verify control room area Once per 4 hours0.167 days 0.0238 weeks 0.00548 months subsystems inoperable. temperature~ 104°F.

AND B.2 Restore one control room AC 7 days subsystem to OPERABLE status.

C. Required Action and C.1 ----------N 0 TE-----------

Associated Completion LCO 3.0.4.a is not Time of Condition A or B applicable when not met in MODE 1, 2, entering MODE 3.

or 3. -----------------------------

Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months (continued)

RIVER BEND 3.7-9 Amendment No. 81119 132 185

-

Control Room AC System 3.7.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and NOTE -

associated Completion LCO 3.0.3 is not applicable.

Time of Condition A not -

met during movement of recently irradiated fuel D.1 Place OPERABLE control Immediately I assemblies in the primary room AC subsystem in containment or fuel operation.

building, or during OPDRVs. OR D.2.1 Suspend movement of Immediately recently irradiated fuel I assemblies in the primary containment and fuel building.

AND D.2.2 Initiate action to Immediately suspend OPDRVs.

(continued)

RIVER BEND 3.7-1 0 Amendment No. 84 44, 132

Control Room AC System 3.7.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. Required Action and E.1 Suspend movement of Immediately associated Completion recently irradiated fuel Time of Condition B not assemblies in the primary met during movement of containment and fuel recently irradiated fuel building.

assemblies in the primary containment or fuel AND building, or during OPDRVs. E.2 Initiate action to suspend Immediately OPDRVs.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.3.1 Verify each control room AC subsystem has the 24 months capability to remove the assumed heat load.

RIVER BEND 3.7-11 Amendment No. 8111Q 132,168

Main Condenser Offgas 3.7.4 3.7 PLANT SYSTEMS 3.7.4 Main Condenser Offgas LCO 3.7.4 The gross gamma activity rate of the noble gases measured prior to the holdup pipe shall be s 290 mCi/second after decay of 30 minutes.

APPLICABILITY: MODE 1, MODES 2 and 3 with any main steam line not isolated and steam jet air ejector (SJAE) in operation.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Gross gamma activity rate A.1 Restore gross gamma 72 hours3 days 0.429 weeks 0.0986 months of the noble gases not activity rate of the noble within limit. gases to within limit.

B. Required Action and B.1 Isolate all main steam 12 hours0.5 days 0.0714 weeks 0.0164 months associated Completion lines.

Time not met.

OR B.2 Isolate SJAE. 12 hours0.5 days 0.0714 weeks 0.0164 months OR B.3 ----------N 0 TE-----------

LCO 3.0.4.a is not applicable when entering MODE 3.

Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months RIVER BEND 3.7-12 Amendment No. 3-i-185

Main Condenser Offgas 3.7.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.1 Verify the gross gamma activity rate of the Once within noble gases is < 290 mCi/second after 4 hours0.167 days 0.0238 weeks 0.00548 months after a decay of 30 minutes. 2 50% increase in the nominal steady state fission gas release rate after factoring out increases due to changes in THERMAL POWER level SR 3.7.4.2 -------------------NOTE--------------------

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

Verify the gross gamma activity rate of the 31 days noble gases is s 290 mCi/second after decay of 30 minutes.

RIVER BEND 3.7-13 Amendment No. 81

Main Turbine Bypass System 3.7.5 3.7 PLANT SYSTEMS 3.7.5 Main Turbine Bypass System LCO 3.7.5 A, The Main Turbine Bypass System shall be OPERABLE.

B. The following limits for inoperable Main Turbine Bypass System, as specified in the COLR are made applicable.

1. LCO 3.2.1, "AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR)," and

2. LCO 3.2.2, "MINIMUM CRITICAL POWER RATIO (MCPR)," and

3. LCO 3.2.3, "LINEAR HEAT GENERATION RATE (LHGR)."

APPLICABI L1TY: THERMAL POWER:?: 23.8 RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A, Main Turbine Bypass A,1 Restore Main Turbine 2 hours0.0833 days 0.0119 weeks 0.00274 months System inoperable. Bypass System to OPERABLE status.

OR A,2 Apply the APLHGR, LHGR 2 hours0.0833 days 0.0119 weeks 0.00274 months and MCPR limits for inoperable Main Turbine Bypass System as specified in the COLR.

B. Required Action and B.1 Reduce THERMAL POWER 4 hours0.167 days 0.0238 weeks 0.00548 months associated Completion to < 23.8% RTP.

Time not met.

RIVER BEND 3.7-14 Amendment No.84-444, 163

Main Turbine Bypass System 3.7.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.1 Verify one complete cycle of each main turbine 31 days bypass valve.

SR 3.7.5.2 Perform a system functional test. 24 months SR 3.7.5.3 Verify the TURBINE BYPASS SYSTEM RESPONSE 24 months TIME is within limits.

RIVER BEND 3.7-14a Amendment No. 811141ed, 168

Fuel Pool Water Level 3.7.6 3.7 PLANT SYSTEMS 3.7.6 Fuel Pool Water Level LCO 3.7.6 The fuel pool water level shall be b 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 COMPLETION TIME A. Fuel pool water level A.1 -------- NOTE---------

not within limit. LCO 3.0.3 is not applicable.

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

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.6.1 Verify the fuel pool water level is 7 days 2 23 ft over the top of irradiated fuel assemblies seated in the storage racks.

RIVER BEND 3.7-15 Amendment No. 81

Control Building Air Conditioning System 3.7.7

3. 7 PLANT SYSTEMS 3.7.7 Control Building Air Conditioning (CBAC) System LCO 3.7.7 Two Control Building Air Conditioning subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One control building air A.1 Restore control building air 72 hours3 days 0.429 weeks 0.0986 months conditioning subsystem conditioning subsystem to inoperable. OPERABLE status.

B. Required Action and 8.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months associated Completion Time of Condition A not AND met.

8.2 Be in MODE 4. 36 hours1.5 days 0.214 weeks 0.0493 months OR Two control building air conditioning subsystems inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.7.1 Verify each Control Building Air Conditioning subsystem 24 months has the capability to remove the assumed heat load.

RIVER BEND 3.7-16 Amendment No. 192

AC Sources-Operating 3.8.1 3.B ELECTRICAL POWER SYSTEMS 3.B.1 AC Sources-Operating LCO 3.B.1 The following AC electrical power sources shall be OPERABLE:

a. Two qualified circuits between the offsite transmission network and the onsite Class 1E AC Electric Power Distribution System; and

b. Three diesel generators (DGs).

APPliCABILITY: MODES 1, 2. and 3.

NOTES---------

1. Division III AC electrical power sources are not requIred to be OPERABLE when High Pressure Core Spray System and Standby Service Water System pump 2C are inoperable.

2. The automatic transfer function for the Division 1114.16 kV system buses shall be OPERABLE whenever the 22 kV onsite circuit Is supplying Division III safety related bus E22-S004 from normal power transformer STX-XNS 1C.

ACTIONS

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

LCO 3.0A.b is not applicable to DGs.

CONDITION REQUIRED ACTION COMPLETION TIME A. One required offsite circuit A.1 Perform SR 3.B.1.1 for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. OPERABLE required offsite circuit. AND Once per 8 hours0.333 days 0.0476 weeks 0.011 months thereafter (continued)

RIVER BEND 3.B-1 Amendment No, ~, 176

AC Sources-Operating 3.8.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) -----NOTE--------

Verification is only required if 22 kV onsite circuit is supplying Division III safety related bus E22 5004 from normal power transformer STX-XNS1 C.

A.2 Verify E22-S004 is 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months aligned to transfer to the preferred station AND transformer powered by the OPERABLE offsite Once per 8 hours0.333 days 0.0476 weeks 0.011 months circuit. thereafter AND A.3 Restore required offsite 72 hours3 days 0.429 weeks 0.0986 months circuit to OPERABLE status. AND 24 hours1 days 0.143 weeks 0.0329 months from discovery of two divisions with no offsite power AND 17 days from discovery of failure to meet Leo B. Automatic transfer function B.1 Restore Division III power 12 hours0.5 days 0.0714 weeks 0.0164 months not OPERABLE source to the preferred station service transformers (continued) I RIVER BEND 3.8-2 Amendment No. ~, 176

AC Sources-Operating 3.8.1 ACTIONS (contlnuedl CONDITION REQUIRED ACTION COMPLETION TIME C. One required DG C.1 Perform SR 3.8.1.1 for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. OPERABLE required offsite circuit(s). ANO Once per 8 hours0.333 days 0.0476 weeks 0.011 months thereafter AND C.2 Declare required 4 hours0.167 days 0.0238 weeks 0.00548 months from discovery feature(s). supported by of Condition C the inoperable OG. concurrent with inoperable when the inoperabllity of redundant required redundant required feature(s) are inoperable. feature(s)

AND (continued)

RIVER BEND 3.&-2a Amendment No. 176 ~

AC Sources-Operating 3.B.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. (continued) C.3.1 Determine OPERABLE 24 hours1 days 0.143 weeks 0.0329 months DG(s) are not inoperable due to common cause failure.

OR C.3.2 Perform SR 3.8.1.2 for 24 hours1 days 0.143 weeks 0.0329 months OPERABLE DG(s).

Mill CA Restore required DG to 12 hours0.5 days 0.0714 weeks 0.0164 months from OPERABLE status. discovery of an inoperable DivisIon ill DG AND 14 days AND 11 days from discovery of failure to meetLCO D. Two required offsite circuits 0.1 Declare requIred 12 hours0.5 days 0.0714 weeks 0.0164 months from inoperable. feature(s) inoperable discovery of when the redundant Condition 0 required feature(s) are concurrent with inoperable. inoperability of redundant required feature(s)

AND 24 hours1 days 0.143 weeks 0.0329 months 0.2 Restore one required oftsite circuit to OPERABLE status.

(contInued)

RIVER BEND 3.8-3 Amendment No. ~, 176

AC Sources-Operating 3.8.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. One required offsite circuit ------------------N 0 TE------------------

inoperable. Enter applicable Conditions and Required Actions of AND LCO 3.8.9, "Distribution Systems-Operating," when any One required DG division is de-energized as a inoperable. result of Condition E.

E.1 Restore required offsite 12 hours0.5 days 0.0714 weeks 0.0164 months circuit to OPERABLE status.

OR E.2 Restore required DG to 12 hours0.5 days 0.0714 weeks 0.0164 months OPERABLE status.

F. Two required DGs F.1 Restore one required 2 hours0.0833 days 0.0119 weeks 0.00274 months inoperable. DG to OPERABLE status. OR 24 hours1 days 0.143 weeks 0.0329 months if Division Ill DG is inoperable G. Required Action and G.1 ----------N 0 TE------------

Associated Completion LCO 3.0.4.a is not Time of Condition A, B, C, applicable when D, E or F not met. entering MODE 3.

Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months H. Three or more required AC H.1 Enter LCO 3.0.3. Immediately sources inoperable.

RIVER BEND 3.8-4 Amendment No. 34- ~ 185

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.1 Verify correct breaker alignment and indicated power 7 days availability for each required offsite circuit.

SR 3.8.1.2 -----------------------------N 0 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 warmup 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 31 days achieves:

a. For DG 1A and DG 1B, steady state voltage

~ 37 40 V and :::; 4368 V and frequency ~ 58.8 Hz and :::; 60.2 Hz.

b. For DG 1C:

1. Maximum of 5400 V, and 66.75 Hz, and

2. Steady state voltage~ 3740 V and

4580 V and frequency ~ 58.8 Hz and

60.2 Hz.

(continued)

RIVER BEND 3.8-5 Amendment No. 81QO121, 187

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.3 ------------------------------N 0 TES------------------------------

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~ 60 minutes at a load

~ 3050 kW ands 3100 kW for DG 1A and DG 1B, and 31 days

~ 2525 kW ands 2600 kW for DG 1C.

SR 3.8.1.4 Verify each day tank contains ;:c: 316.3 gal of fuel oil. 31 days SR 3.8.1.5 Check for and remove accumulated water from each 31 days day tank.

SR 3.8.1.6 Verify the fuel oil transfer system operates to 31 days automatically transfer fuel oil from the storage tank to the day tank.

(continued)

RIVER BEND 3.8-6 Amendment No. 81 90 121, 187

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.7 -------------------------N 0 TE-------------------------------------

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

Verify each DG starts from standby conditions and 184 days achieves:

a. For DG 1A and DG 1B:

1. Ins 10 seconds, voltage~ 3740 V and frequency ~ 58.8 Hz; and

2. Steady state voltage~ 3740 V ands 4368 V and frequency ~ 58.8 Hz and s 60.2 Hz.

b. For DG 1C:

1. Maximum of 5400 V, and 66.75 Hz, and

2. Ins 13 seconds, voltage~ 3740 V and frequency ~ 58.8 Hz; and

3. Steady state voltage~ 3740 V ands 4580 V and frequency~ 58.8 Hz and s 60.2 Hz.

SR 3.8.1.8 -------------------------------N 0 TES--------------------------------

1. This Surveillance shall not be performed in MODE 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 1C.

a. Verify manual transfer of unit power supply from the normal offsite circuit to required alternate offsite 24 months circuit.

b. Verify automatic transfer of bus E22-S004 through NNS-SWG1A or NNS-SWG1 B from the22 kV onsite 24 months circuit to required offsite circuit.

(continued)

RIVER BEND 3.8-7 Amendment No. 81 121 165 168 176, 187

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.9 ------------------------------N 0 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 24 months 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.

SR 3.8.1.10 ------------------------------N 0 TE-------------------------------

Cred it may be taken for unplanned events that satisfy this SR.

Verify each DG operating at a power factor :5: 0.9 does 24 months not trip and voltage is maintained :5: 4784 V for DG 1A and DG 1B and :5: 5400 V for DG 1C during and following a load rejection of a load e: 3050 kW and

5: 3130 kW for DGs 1A and 1Bande:2525 kW and

5: 2600 kW for DG 1C.

(continued)

RIVER BEND 3.8-8 Amendment No. 81 121 133 137 168, 187

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.11 ----------------------------------N 0 TES--------------------------

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 1C)

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

Verify on an actual or simulated loss of offsite power 24 months signal:

a. De-energization of emergency buses;

b. Load shedding from emergency buses for Divisions I and II; and

c. DG auto-starts from standby condition and:

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

2. energizes auto-connected shutdown loads,

3. maintains steady state voltage

i. for DG 1A and DG 18;;:: 3740 V and s 4368 V, ii. for DG 1C;;:: 3740 Vand s 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)

RIVER BEND 3.8-9 Amendment No. 81 121 133 108, 187

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.12 -------------------------------N 0 TES-----------------------------

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 1C)

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

Verify on an actual or simulated Emergency Core 24 months Cooling System (ECCS) initiation signal each DG auto-starts from standby condition and:

a. For DG 1C during the auto-start maintains voltage :s; 5400 V and frequency :s; 66.75 Hz;

b. In :s; 10 seconds for DG 1A and DG 18 and

s; 13 seconds for DG 1C after auto-start and during tests, achieves voltage ~ 3740 V and frequency ~ 58.8 Hz.

c. Achieves steady state voltage

1. For DG 1A and DG 18 ~ 3740 V and

s; 4368 V,

2. For DG 1C ~ 3740 V and :s; 4580 V, and

3. For DG 1A, 1B, and 1C, frequency of

~ 58.8 and :s; 60.2 Hz; and

d. Operates for~ 5 minutes.

(continued)

RIVER BEND 3.8-10 Amendment No. 81 121133 165 168, 187

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.13 ----------------------------N 0 TE---------------------------

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

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

Verify each DG's automatic trips are bypassed on 24 months an actual or simulated ECCS initiation signal except

a. Engine overspeed; and

b. Generator differential current.

SR 3.8.1.14 ---------------------------N 0 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 factor:::::; 0.9, 24 months operates for 2 24 hours1 days 0.143 weeks 0.0329 months :

a. For DG 1A and DG 1B loaded 2 3050 kW and:::::; 3130 kW; and

b. For DG 1C:

1. For 2 2 hours0.0833 days 0.0119 weeks 0.00274 months loaded 2 2750 kW and

: :; 2850 kW, and

2. For the remaining hours of the test loaded 2 2525 kW and .$; 2600 kW.

(continued)

RIVER BEND 3.8-11 Amendment No. 81 Q4 121 133 168, 187

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.15 -----------------------------N 0 TES-------------------------------

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 1C, 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:

24 months

1. In :s; 10 seconds for DG 1A and DG 18 and

s; 13 seconds for DG 1C voltage ~ 3740 V and frequency ~ 58.8 Hz, and

2. Steady state voltage a) For DG 1A and DG 18 ~ 3740 V and

s; 4368 v b) For DG 1C ~ 3740 V and :s; 4580 V and c) For DG 1A, 1B, and 1C frequency

~ 58.8 Hz and :s; &+60.2 Hz.

(continued) j RIVER BEND 3.8-12 Amendment No. 81 121133 165 168, 187

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.16 ----------------------------NO TE--------------------------------

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

Verify each DG: 24 months

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.

SR 3.8.1.17 ------------------------------N 0 TE--------------------------------

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

Verify, with a DG operating in test mode and 24 months 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.

SR 3.8.1.18 ------------------------------N 0 TE--------------------------------

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

Verify sequence time is within +/- 10% of design for each 24 months load sequencer timer.

(continued)

RIVER BEND 3.8-13 Amendment No. 81 Q5 121 133 168, 187

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued SURVEILLANCE FREQUENCY SR 3.8.1.19 -------------------------------N 0 TES-----------------------------

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 1C)

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

Verify, on an actual or simulated loss of offsite power 24 months 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 II; and

c. DG auto-starts from standby condition and:

1. energizes permanently connected loads in s 10 seconds for DG 1A and DG 18 and s 13 seconds for DG 1C,

2. energizes auto-connected emergency loads,

3. achieves steady state voltage

i. for DG 1A and DG 18 ~ 3740 Vand

s:4368 V, ii. for DG 1C ~ 3740 V ands 4580 V,

4. achieves steady state frequency~ 58.8 Hz and s 60.2 Hz, and

5. supplies permanently connected and auto-connected emergency loads for

~ 5 minutes.

(continued)

RIVER BEND 3.8-14 Amendment No. 81121 1aa 168, 187

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.20 ------------------------------N 0 TE--------------------------------

A 11 DG starts may be preceded by an engine prelube period.

Verify, when started simultaneously from standby 10 years condition, each DG achieves:

1. In::;; 10 seconds for DG 1A and DG 1Band

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

2. Steady state voltage a) For DG 1A and DG 1B ~ 3740 V and

4368 V, b) For DG 1C ~ 3740 V and

: ;; 4580 V, and c) For DG 1A, 18, and 1C a frequency~ 58.8 Hz and ::;; 60.2 Hz.

RIVER BEND 3.8-15 Amendment No. 81 121 165, 187

- -

AC Sources-Operating 3.8.1 I Table 3.8.1-1 has been deleted RIVER BEND 3.8-16 Amendment No. 81, 90 JANKI 4 ;.37

AC Sources-Shutdown 3.8.2 3.8 ELECTRICAL POWER SYSTEMS 3.8.2 AC Sources-Shutdown LCO 3.8.2 The following AC electrical power sources shall be OPERABLE:

a. One qualified circuit between the offsite transmission network and the onsite Class 1E AC electrical power distribution subsystem(s) required by LCO 3.8.10, "Distribution Systems-Shutdown";

b. One diesel generator (DG) capable of supplying one division of the Division I or 11onsite Class 1E AC electrical power distribution subsystem(s) required by LCO 3.8.10; and

c. One qualified circuit, other than the circuit in LCO 3.8.2.a, between the offsite transmission and the Division IlIl onsite Class IE electrical power distribution subsystem, or the Division IlIl DG capable of supplying the Division IlIl onsite Class 1E AC electrical power distribution subsystem, when the Division III onsite Class 1E electrical power distribution subsystem is required by LCO 3.8.10.

APPLICABILITY: MODES 4 and 5, During movement of recently irradiated fuel assemblies in the primary containment or fuel building.

RIVER BEND 3.8-1 7 Amendment No. 84 5, 132

AC Sources-Shutdown 3.8.2 ACTIONS

-NOTE----

LCO 3.0.3 is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. LCO Item a not met. NOTE Enter applicable Condition and Required Actions of LCO 3.8.10, when any required division is de-energized as a result of Condition A.

A.1 Declare affected Immediately required feature(s) with no offsite power available from a required circuit inoperable.

OR A.2.1 Suspend CORE Immediately ALTERATIONS.

AND A.2.2 Suspend movement of Immediately recently irradiated fuel assemblies in the I

primary containment and fuel building.

AND A.2.3 Initiate action to Immediately suspend operations with a potential for draining the reactor vessel (OPDRVs).

AND (continued)

RIVER BEND 3.8-1 8 Amendment No. 84, 132

AC Sources-Shutdown 3.8.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.4 Initiate action to restore Immediately required offsite power circuit to OPERABLE status.

B. LCO Item b not met. B.1 Suspend CORE Immediately ALTERATIONS.

AND Immediately B.2 Suspend movement of recently irradiated fuel assemblies in primary I

containment and fuel building.

AND Immediately B.3 Initiate action to suspend OPDRVs.

AND Immediately B.4 Initiate action to restore required DG to OPERABLE status.

C. LCO Item c not met. C.1 Declare High Pressure 72 hours3 days 0.429 weeks 0.0986 months Core Spray System and Standby Service Water System pump 2C inoperable.

RIVER BEND 3.8-1 9 Amendment No. 04-, 132

- -

AC Sources - Shutdown 3.8.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY 4.

SR 3.8.2.1 --------------- NOTE--------------------

The following SRs are not required to be performed: SR 3.8.1.3. SR 3.8.1.9 through SR 3.8.1.11. SR 3.8.1.13 through SR 3.8.1.16.

SR 3.8.1.18. and SR 3.8.1.19.

For AC sources required to be OPERABLE. the In accordance following SRs are applicable: with applicable SRs SR 3.8.1.1 SR 3.8.1.7 SR 3.8.1.14 SR 3.8.1.2 SR 3.8.1.9 SR 3.8.1.15 SR 3.8.1.3 SR 3.8.1.10 SR 3.8.1.16 SR 3.8.1.4 SR 3.8.1.11 SR 3.8.1.18 SR 3.8.1.5 SR 3.8.1.12 SR 3.8.1.19 SR 3.8.1.6 SR 3.8.1.13 RIVER BEND 3.8-20 Amendment No. e;. 121

Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 3.8 ELECTRICAL POWER SYSTEMS 3.8.3 Diesel Fuel Oil, Lube Oil, and Starting Air LCO 3.8.3 The stored diesel fuel oil, lube oil, and starting air subsystem shall be within limits for each-required diesel generator (DG).

APPLICABILITY: When associated DG is required to be OPERABLE.

ACTIONS

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

Separate Condition entry is allowed for each DG.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more DGs with A.1 Restore fuel oil 48 hours2 days 0.286 weeks 0.0658 months fuel oil level level to within

< 45,495 gal and limits.

2 38,996 gal.

B. One or more DGs with B.1 Restore lube oil 48 hours2 days 0.286 weeks 0.0658 months lube oil inventory: inventory to within limits.

1. For DG IA or IB,

< 367 gal and 2 350 gal; and

2. For DG IC, < 295 gal and 2 265 gal.

C. One or more DGs with C.1 Restore fuel oil 7 days stored fuel oil total total particulates to particulates not within limit.

within limit.

(continued)

RIVER BEND 3.8-21 Amendment No. 81

Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. One or more DGs with D.1 Restore stored fuel 30 days new fuel oil oil properties to properties not within within limits.

limits.

E. Required Actions and E.1 .Declare associated DG Immediately associated Completion inoperable.

Time not met.

OR One or more DGs with diesel fuel oil, lube oil, or starting air subsystem not within limits for reasons other than Condition A, B, C, or D.

RIVER BEND 3.8-22 Amendment No. 81

Diesel Fuel Oil, Lube Oil, and Starting.Air 3.8.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.3.1 Verify each fu'l oil storage tank contains > 45,495 gal 31 days of fuel.

SR 3.8.3.2 Verify lube oil inventory is: 31 days

a. Ž367 gal for DGs 1A and iB; and

b. Ž295 gal for DG lC.

SR 3.8.3.3 Verify fuel oil properties of new and stored fuel oil are In accordance with tested in accordance with, and maintained within the the Diesel Fuel Oil limits of, the Diesel Fuel Oil Testing Program. Testing Program SR 3.8.3.4 Verify each required DG air start receiver pressure is 31 days

a. Ž 160 psig for DGs 1A and 1B; and

b. _200 psig for DG 1C.

SR 3.8.3.5 Check for and remove accumulated water from each 31 days fuel oil storage tank.

SR 3.8.3.6 Deleted RIVER BEND 3.8-23 Amendment No. 8-91.-9, 160

DC Sources-Operating 3.8.4 3.8 ELECTRICAL POWER SYSTEMS 3.8.4 DC Sources-Operating LCO 3.8.4 The Division I, Division II, and Division Ill DC electrical power subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required battery A.1 Restore battery terminal 2 hours0.0833 days 0.0119 weeks 0.00274 months charger on Division I or 11 voltage to greater than or inoperable. equal to the minimum established float voltage.

AND A.2 Verify battery float current Once per 12 hours0.5 days 0.0714 weeks 0.0164 months s 2 amps.

AND A.3 Restore battery charger to 7 days OPERABLE status.

B. Division I or 11 DC B.1 Restore Division I and 11 2 hours0.0833 days 0.0119 weeks 0.00274 months electrical power DC electrical power subsystem inoperable for subsystems to OPERABLE reasons other than status.

Condition A.

C. Division 111 DC electrical C.1 Declare High Pressure Immediately power subsystem Core Spray System and inoperable. Standby Service Water System pump 2C inoperable.

D. Required Action and D.1 -----------N 0 TE-----------

associated Completion LCO 3.0.4.a is not Time for Division I or 11 applicable when DC electrical power entering MODE 3.

subsystem not met. ------------------------------

Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months (continued) I RIVER BEND 3.8-24 Amendment No. 81 148 185

DC Sources-Operating 3.8.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. Required Action and E.1 Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months associated Completion Time for Division Ill DC AND electrical power subsystem not met. E.2 Be in MODE 4. 36 hours1.5 days 0.214 weeks 0.0493 months RIVER BEND 3.8-24a Amendment No. 81 148 185

DC Sources-Operating 3.8.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.4.1 Verify battery terminal voltage is:<: 130.2 Von float 7 days charge.

SR 3.8.4.2 Verify no visible corrosion at battery terminals and 92 days connectors.

Verify battery connection resistance is

~ 1.5 E-4 ohm for inter-cell connections,

~ 1.5 E-4 ohm for inter-rack connections,

~ 1.5 E-4 ohm for inter-tier connections, and

~ 1.5 E-4 ohm for terminal connections.

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

SR 3.8.4.3 Verify battery cells, cell plates, and racks show no 24 months visual indication of physical damage or abnormal deterioration.

SR 3.8.4.4 Remove visible corrosion, and verify battery cell to 24 months cell and terminal connections are coated With anti-corrosion material.

SR 3.8.4.5 Verify battery connection resistance is 24 months

~ 1.5 E-4 ohm for inter-cell connections,

~ 1.5 E-4 ohm for inter-rack connections,

~ 1.5 E-4 ohm for inter-tier connections, and

~ 1.5 E-4 ohm for terminal connections.

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

(continued)

I RIVER BEND 3.8-25 Amendment No.8-+, +68 181

DC Sources-Operating 3.8.4 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.4.6 Verify each battery charger supplies ~ 300 amps for 24 months chargers 1A and 1B and ~ 50 amps for charger 1C at

~ 130.2 V for ~ 8 hours0.333 days 0.0476 weeks 0.011 months .

SR 3.8.4.7 -----------------------------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 III).

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

Verify battery capacity is adequate to supply, and 24 months maintain in OPERABLE status, the required emergency loads for the design duty cycle when subjected to a battery service test.

(continued)

RIVER BEND 3.8-26 Amendment No. 81 141, 168

DC Sources-Operating 3.8.4 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.4.8 --- ----- NOTE----- ------

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

Verify battery capacity is 2 80% of the manufacturer's 60 months rating when subjected to a performance discharge test. AND

--- NOTE-Only applicable when battery shows degradation or has reached 85% of expected life.

18 months RIVER BEND 3.8-27 Amendment No. 141

DC Sources-Shutdown 3.8.5 3.8 ELECTRICAL POWER SYSTEMS 3.8.5 DC Sources-Shutdown LCO 3.8.5 The following shall be OPERABLE:

a. One Class I E DC electrical power subsystem capable of supplying one division of the Division I or 11onsite Class 1E DC electrical power distribution subsystem(s) required by LCO 3.8.10, "Distribution Systems-Shutdown";

b. One Class 1E battery or battery charger, other than the DC electrical power subsystem in LCO 3.8.5.a, capable of supplying the remaining Division I or 11onsite Class 1E DC electrical power distribution subsystem(s) when required by LCO 3.8.10; and

c. The Division IlIl DC electrical power subsystem capable of supplying the Division IlIl onsite Class 1E DC electrical power distribution subsystem, when the Division IlIl onsite Class 1E DC electrical power distribution subsystem is required by LCO 3.8.10.

APPLICABILITY: MODES 4 and 5, During movement of recently irradiated fuel assemblies in the primary containment or fuel building.

RIVER BEND 3.8-28 Amendment No. 84, 132

-

DC Sources-Shutdown 3.8.5 ACTIONS sensc

-- rNu IIC LCO 3.0.3 is not applicable CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required DC A.1 Declare affected Immediately electrical power required feature(s) subsystems inoperable. inoperable.

OR A.2.1 Suspend CORE Immediately ALTERATIONS.

AND A.2.2 Suspend movement of Immediately recently irradiated fuel assemblies in the I

primary containment and fuel building.

AND A.2.3 Initiate action to Immediately suspend operations with a potential for draining the reactor vessel.

AND A.2.4 Initiate action to restore Immediately required DC electrical power subsystems to OPERABLE status.

RIVER BEND 3.8-29 Amendment No. 84, 132

DC Sources-Shutdown 3.8.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.5.1 --------------------NOTE ------------------

The following SRs are not required to be performed: SR 3.8.4.4, SR 3.8.4.6, SR 3.8.4.7, and SR 3.8.4.8.

For DC sources required to be OPERABLE, the In accordance following SRs are applicable: with applicable SRs SR 3.8.4.1 SR 3.8.4.4 SR 3.8.4.7 SR 3.8.4.2 SR 3.8.4.5 SR 3.8.4.8.

SR 3.8.4.3 SR 3.8.4.6 RIVER BEND 3.8-30 Amendment No. 81

Battery Cell Parameters 3.8.6 3.8 ELECTRICAL POWER SYSTEMS 3.8.6 Battery Cell Parameters LCO 3.8.6 Battery cell parameters for the Division I, II, and III batteries shall be within the limits of Table 3.8.6-1.

APPLICABILITY: When associated DC electrical power subsystems are required to be OPERABLE.

ACTIONS

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

Separate Condition entry is allowed for each battery.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more batteries A.1 Verify pilot cell's 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months with one or more electrolyte level and battery cell float voltage meet parameters not within Table 3.8.6-1 Table 3.8.6-1 Category Category C limits.

A or B limits.

AND A.2 Verify battery cell 24 hours1 days 0.143 weeks 0.0329 months parameters meet Table 3.8.6-1 AND Category C limits.

Once per 7 days thereafter AND A.3 Restore battery cell 31 days parameters to Category A and B limits of Table 3.8.6-1.

(continued)

RIVER BEND 3.8-31 Amendment No. 81

Battery Cell Parameters 3.8.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Declare associated Immediately associated Completion battery inoperable.

Time of Condition A not met.

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

< 600F.

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

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.1 Verify battery cell parameters meet 7 days Table 3.8.6-1 Category A limits.

(continued)

RIVER BEND 3.8-32 Amendment No. 81

Battery Cell Parameters 3.8.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.6.2 Verify battery cell parameters meet 92 days Table 3.8.6-1 Category B limits.

AND Once within 72 hours3 days 0.429 weeks 0.0986 months after battery overcharge

> 144 V SR 3.8.6.3 Verify average electrolyte temperature of 92 days representative cells is ; 600F.

RIYER BEND 3.8-33 Amendment No. 81

Battery Cell Parameters 3.8.6 Table 3.8.6-1 (page 1 of 1)

Battery Cell Parameter Requirements CATEGORY A:

LIMITS FOR EACH CATEGORY B: CATEGORY C:

DESIGNATED PILOT LIMITS FOR EACH LIMITS FOR EACH PARAMETER CELL CONNECTED CELL CONNECTED CELL Electrolyte > Minimum level > Minimum level Above top of Level indication mark, *indication mark, plates, and not and

1/4 inch and

1/4 inch overflowing above maximum above maximum level indication level indication mark(a) mark(a)

Float Voltage 2 2.13 V 2 2.13 V 2 2.07 V Specific 2 1.200 2 1.195 Not more than 0.020 Gravity(b)(c) below average of AND all connected cells Average of all AND connected cells 2 1.205 Average of all connected cells 2 1.195 (a) It is acceptable for the electrolyte level to temporarily increase above the specified maximum level during equalizing charges provided it is not overflowing.

(b) Corrected for electrolyte temperature and level. Level correction is not required. however, when battery charging is < 2 amps when on float charge.

(c) A battery charging current of < 2 amps when on float charge is acceptable for meeting specific gravity limits following a battery recharge. for a maximum of 31 days. When charging current is used to satisfy specific gravity requirements, specific gravity of each connected cell shall be measured prior to expiration of the 31 day allowance.

RIVER BEND 3.8-34 Amendment No. 81. 103 MIAR 0 3 199

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

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

N0 TE-----------------------------------------------------------------

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

CONDITION REQUIRED ACTION COMPLETION TIME A. Division I or II inverter A.1 Restore Division I and 11 24 hours1 days 0.143 weeks 0.0329 months inoperable. inverters to OPERABLE status.

B. Required Action and B.1 ------------N 0 TE-------------

associated Completion LCO 3.0.4.a is not Time of Condition A not applicable when entering met. MODE 3.

Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.7.1 Verify correct inverter voltage, frequency, and 7 days alignment to required AC vital buses.

RIVER BEND 3.8-35 Amendment No. ~ 185

Inverters-Shutdown 3.8.8 3.8 ELECTRICAL POWER SYSTEMS 3.8.8 Inverters-Shutdown LCO 3.8.8 One Divisional inverter shall be OPERABLE capable of supplying one division of the Division I or If onsite Class I E uninterruptible AC vital bus electrical power distribution subsystem(s) required by LCO 3.8.1 0, "Distribution Systems-Shutdown".

APPLICABILITY: MODES 4 and 5, During movement of recently irradiated fuel assemblies in the primary I containment or fuel building.

ACTIONS LCO 3.0.3 is not applicable CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Declare affected Immediately inverters inoperable. required feature(s) inoperable.

OR A.2.1 Suspend CORE Immediately ALTERATIONS.

AND A.2.2 Suspend handling of Immediately recently irradiated fuel assemblies in the I

primary containment or fuel building.

AND (continued)

RIVER BEND 3.8-36 Amendment No. "4. 132

-

Inverters-Shutdown 3.8.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.3 Initiate action to Immediately suspend operations with a potential for draining the reactor vessel.

AND A.2.4 Initiate action to Immediately restore required inverters to OPERABLE status.

SURVEILLANCE REQUIREMENTS _

SURVEILLANCE FREQUENCY SR 3.8.8.1 Verify correct inverter voltage, frequency, 7 days and alignments to required AC vital buses.

RIVER BEND 3.8-37 Amendment No. 81

Distribution Systems-Operating 3.8.9 3.8 ELECTRICAL POWER SYSTEMS 3.8.9 Distribution Systems-Operating LCO 3.8.9 Division I, Division II, and Division III AC and DC, and Division I and II AC vital bus electrical power distribution subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

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

Division III electrical power distribution subsystems are not required to be OPERABLE when High Pressure Core Spray System and Standby Service Water pump 2C are inoperable.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more Division I A.1 Restore Division I 8 hours0.333 days 0.0476 weeks 0.011 months or II AC electrical and II AC electrical power distribution power distribution AND subsystems inoperable. subsystems to OPERABLE status. 16 hours0.667 days 0.0952 weeks 0.0219 months from discovery of failure to meet LCO B. One or more Division I B.1 Restore Division I 8 hours0.333 days 0.0476 weeks 0.011 months or II AC vital bus and II AC vital bus distribution distribution AND subsystems inoperable. subsystems to OPERABLE status. 16 hours0.667 days 0.0952 weeks 0.0219 months from discovery of failure to meet LCO (continued)

RIVER BEND 3.8-38 Amendment No. 81

Distribution Systems-Operating 3.8.9 ACTION (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One or more Division I or 11 C.1 Restore Division I and II 2 hours0.0833 days 0.0119 weeks 0.00274 months DC electrical power DC electrical power distribution subsystems distribution subsystems AND inoperable. to OPERABLE status.

16 hours0.667 days 0.0952 weeks 0.0219 months from discovery of failure to meet LCO D. Required Action and D.1 -----------N 0 TE-------------

associated Completion LCO 3.0.4.a is not Time of Condition A, B, applicable when or C not met. entering MODE 3.

Be in MODE 3. 12 hours0.5 days 0.0714 weeks 0.0164 months E. One or more Division 111 E.1 Declare High Pressure Immediately AC or DC electrical power Core Spray System and distribution subsystems Standby Service Water inoperable. System pump 2C inoperable.

F. Two or more divisions with F.1 Enter LCO 3.0.3. Immediately inoperable distribution subsystems that result in a loss of function.

RIVER BEND 3.8-39 Amendment No. ~ .Qa 185

Distribution Systems-Operating 3.8.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.9.1 Verify correct breaker alignments and 7 days voltage to required AC, DC, and AC vital bus electrical power distribution subsystems.

RIVER BEND 3.8-40 Amendment No. 81

Distribution Systems-Shutdown 3.8.10 3.8 ELECTRICAL POWER SYSTEMS 3.8.10 Distribution Systems-Shutdown LCO 3.8.10 The necessary portions of the Division I, Division II, and Division III AC, DC, and Division I and 11AC vital bus electrical power distribution subsystems shall be OPERABLE to support equipment required to be OPERABLE.

APPLICABILITY: MODES 4 and 5, During movement of recently irradiated fuel assemblies in the primary I containment or fuel building.

ACTIONS I--___

LCO 3.0.3 is not applicable CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Declare associated Immediately AC, DC, or AC vital bus supported required electrical power feature(s) inoperable.

distribution subsystems inoperable. OR A.2.1 Suspend CORE Immediately ALTERATIONS.

AND A.2.2 Suspend movement of Immediately

-

recently irradiated fuel

--assemblies in the I

primary containment and fuel building.

AND (continued)

RIVER BEND 3.8-41 Amendment No. 84, 132

Distribution Systems -Shutdown 3.8.10 ACTIONS CONDITION 'REQUIRED ACTION COMPLETION TIME A. (continued) A.2.3 Initiate action to Immediately suspend operations with a potential for draining the reactor vessel.

AND A.2.4 Initiate actions to Immediately restore required AC, DC, and AC vital bus electrical power distribution subsystems to OPERABLE status.

AND A.2.5 Declare associated Immediately required shutdown cooling subsystem(s) inoperable and not in operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.10.1 Verify correct breaker alignments and 7 days voltage to required AC, DC, and AC vital bus electrical power distribution subsystems.

RIVER BEND 3.8-42 Amendment No. 81

-. 1 Refueling Equipment Interlocks 3.9.1 3.9 REFUELING OPERATIONS 3.9.1 Refueling Equipment Interlocks LCO 3.9.1 The refueling equipment interlocks shall be OPERABLE.

APPLICABILITY: During in-vessel fuel movement with equipment associated with the interlocks.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Suspend in-vessel fuel Immediately refueling equipment movement with equipment interlocks inoperable. associated with the inoperable interlock(s).

OR A.2.1 Insert a control rod Immediately withdrawal block.

AND A.2:2 Verify all control rods Immediately are fully inserted in core cells containing one or more fuel assemblies.

RIVER BEND 3.9-1 Amendment No. AdN 104 MAR 2 6 1999

Refueling Equipment Interlocks 3.9.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY 4.

SR 3.9.1.1 Perform CHANNEL FUNCTIONAL TEST on each of the 7 days following required refueling equipment interlock inputs:

a. All-rods-in,

b. Refuel platform position. and

c. Refuel platform main hoist, fuel loaded.

RIVER BEND 3.9-la Amendment 06'1994 WA -2'64199,9

Refuel 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- A.1 Suspend control rod Immediately rod-out interlock withdrawal.

inoperable.

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

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.2.1 Verify reactor mode switch locked in refuel 12 hours0.5 days 0.0714 weeks 0.0164 months position.

(continued)

RIVER BEND 3.9-2 Amendment No. 81

Refuel Position One-Rod-Out Interlock 3.9.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.9.2.2 -------------------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. 7 days RIVER BEND 3.9-3 Amendment No. 81

Control Rod Position 3.9.3 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 REQUIRED ACTION COMPLETION TIME A. One or more control A.1 Suspend loading fuel Immediately rods not fully assemblies into the inserted. core.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.3.1 Verify all control rods are fully inserted. 12 hours0.5 days 0.0714 weeks 0.0164 months RIVER BEND 3.9-4 Amendment No. 81

Control Rod Position Indication 3.9.4 3.9 REFUELING OPERATIONS 3.9.4 Control Rod Position Indication LCO 3.9.4 One control rod "full-in" position indication channel for each control rod shall be OPERABLE.

APPLICABILITY: MODE 5.

ACTIONS

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

Separate Condition entry is allowed for each required channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1.1 Suspend in-vessel Immediately control rod position fuel movement.

indication channels inoperable. AND A.1.2 Suspend control rod Immediately withdrawal.

AND A.1.3 Initiate action to Immediately fully insert all insertable control rods in core cells containing one or more fuel assemblies.

OR (continued)

RIVER BEND 3.9-5 Amendment No. 81

Control Rod Position Indication 3.9.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.1 Initiate action to Immediately fully insert the control rod associated with the inoperable position indicator.

AND A.2.2 Initiate action to Immediately disarm the control rod drive associated with the fully inserted control rod.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.4.1 Verify the required channel has no "full- Each time the in" indication for each control rod that is control rod is not "full-in." withdrawn from the "full-in" position RIVER BEND 3.9-6 Amendment No. 81

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

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.5.1 -------------------NOTE--------------------

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

Insert each withdrawn control rod at least one 7 days notch.

SR 3.9.5.2 Verify each withdrawn control rod scram 7 days I accumulator pressure is 2 1540 psig.

RIVER BEND 3.9-7 Amendment No. 8.,114 OCT 0 6 2000

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 2 23 ft above the top of the RPV flange.

APPLICABILITY: During movement of irradiated fuel assemblies within the RPV.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RPV water level not A.1 Suspend movement of Immediately within limit. irradiated fuel assemblies within the RPV.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.6.1 Verify RPV water level is 2 23 ft above 24 hours1 days 0.143 weeks 0.0329 months the top of the RPV flange.

RIVER BEND 3.9-8 Amendment No. 81

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 A.1 Suspend movement of Immediately within limit. new fuel assemblies and handling of control rods within the RPV.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.7.1 Verify RPV water level is z 23 ft above 24 hours1 days 0.143 weeks 0.0329 months the top of irradiated fuel assemblies seated within the RPV.

RIVER BEND 3.9-9 Amendment No. 81

RHR-High Water Level 3.9.8 3.9 REFUELING OPERATIONS 3.9.8 Residual Heat Removal (RHR) -High Water Level LCO 3.9.8 One RHR shutdown cooling subsystem shall be OPERABLE and in operation.

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

The required RHR shutdown cooling subsystem may be removed from operation for up to 2 hours0.0833 days 0.0119 weeks 0.00274 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period.

APPLICABILITY: MODE 5 with irradiated fuel in the reactor pressure vessel (RPV) and the water level > 23 ft above the top of the RPV flange.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Required RHR shutdown A.1 Verify an alternate 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months cooling subsystem method of decay heat inoperable. removal is available. AND Once per 24 hours1 days 0.143 weeks 0.0329 months thereafter B. Required Action and B.1 Suspend loading Immediately associated Completion irradiated fuel Time of Condition A assemblies into the not met. RPV.

AND B.2 Initiate action to Immediately restore primary containment to OPERABLE status.

AND (continued)

RIVER BEND 3 .9-10 Amendment No. 81

RHR - High Water Level 3.9.8 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.3 -----------N 0 TE------------

Entry and exit is permissible under administrative control.

Initiate action to close Immediately one door in each primary containment air lock.

C. No RHR shutdown cooling C.1 Verify reactor coolant 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from subsystem in operation. circulation by an discovery of no alternate method. reactor coolant circulation AND Once per 12 hours0.5 days 0.0714 weeks 0.0164 months thereafter AND C.2 Monitor reactor coolant Once per hour temperature.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.8.1 Verify one RHR shutdown cooling subsystem is 12 hours0.5 days 0.0714 weeks 0.0164 months operating.

SR 3.9.8.2 Verify required RHR shutdown cooling subsystem 31 days locations susceptible to gas accumulation are sufficiently filled with water.

RIVER BEND 3.9-11 Amendment No. 84, 188

RHR-Low Water Level 3.9.9 3.9 REFUELING OPERATIONS 3.9.9 Residual Heat Removal (RHR) -Low Water Level LCO 3.9.9 Two RHR shutdown cooling subsystems shall be OPERABLE, and one RHR shutdown cooling subsystem shall be in operation.

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

The required operating shutdown cooling subsystem may be removed from operation for up to 2 hours0.0833 days 0.0119 weeks 0.00274 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period.

APPLICABILITY: MODE 5 with irradiated fuel in the reactor pressure vessel (RPV) and the water level < 23 ft above the top of the RPV flange.

ACTIONS

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

Separate Condition entry is allowed for each subsystem.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or two RHR A.1 Verify an alternate 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months shutdown cooling method of decay heat subsystems inoperable, removal is available AND for each inoperable RHR shutdown cooling Once per subsystem. 24 hours1 days 0.143 weeks 0.0329 months thereafter B. Required Action and B.1 Initiate action to Immediately associated Completion restore primary Time of Condition A containment to not met. OPERABLE status.

AND (continued)

RIVER BEND 3.9-12 Amendment No. 81

RHR - Low Water Level 3.9.9 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.2 -----------NOTE-----------

Entry and exit is permissible under administrative control.

Initiate action to close Immediately one door in each primary containment air lock.

C. No RHR shutdown cooling C.1 Verify reactor coolant 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from discovery subsystem in operation. circulation by an of no reactor coolant alternate method. circulation AND Once per 12 hours0.5 days 0.0714 weeks 0.0164 months thereafter AND C.2 Monitor reactor coolant Once per hour temperature.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.9.1 Verify one RHR shutdown cooling subsystem is 12 hours0.5 days 0.0714 weeks 0.0164 months operating.

SR 3.9.9.2 Verify required RHR shutdown cooling subsystem 31 days locations susceptible to gas accumulation are sufficiently filled with water.

RIVER BEND 3.9-13 Amendment No. &+, 188

Inservice Leak and Hydrostatic Testing Operation 3.10.1 3.10 SPECIAL OPERATIONS 3.10.1 Inservice Leak and Hydrostatic Testing Operation LCO 3.10.1 The average reactor coolant temperature specified in Table 1.1-1 for MODE 4 may be changed to "NA," and operation considered not to be in MODE 3; and the requirements of LCO 3.4.10, "Residual Heat Removal (RHR) Shutdown Cooling System - Cold Shutdown," may be suspended, to allow reactor coolant temperature> 200°F:

For performance of an inservice leak or hydrostatic test,

As a consequence of maintaining adequate pressure for an inservice leak or hydrostatic test, or

As a consequence of maintaining adequate pressure for control rod scram time testing initiated in conjunction with an inservice leak or hydrostatic test, provided the following MODE 3 LCOs are met:

a. LCO 3.3.6.2, "Secondary Containment and Fuel Building Isolation Instrumentation," Functions 1, 2, and 5 of Table 3.3.6.2-1;

b. LCO 3.6.4.1, "Secondary Containment - Operating";

c. LCO 3.6.4.2, "Secondary Containment Isolation Dampers (SCIDs) and Fuel Building Isolation Dampers (FBIDs)";

d. LCO 3.6.4.3, "Standby Gas Treatment (SGT) System"; and

e. LCO 3.6.4.5, "Fuel Building."

APPLICABILITY: MODE 4 with average reactor coolant temperature> 200°F.

RIVER BEND 3.10-1 Amendment No. 81113143,170

Inservice Leak and Hydrostatic Testing Operation 3.10.1 ACTIONS

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

Separate Condition entry is allowed for each requirement of the LCO.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more of the A.1 -------- NOTE---------

above requirements not Required Actions to met. be in MODE 4 include reducing average reactor coolant temperature to s 200 0F.

Enter the applicable Immediately Condition of the affected LCO.

OR A.2.1 Suspend activities Immediately that could increase the average reactor coolant temperature or pressure.

AND A.2.2 Reduce average 24 hours1 days 0.143 weeks 0.0329 months reactor coolant temperature to s 200 0F.

RIVER BEND 3.10-2 Amendment No. 81

Inservice Leak and Hydrostatic Testing Operation 3.10.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.1.1 Perform the applicable Sks for the required According to MODE 3 LCOs. the applicable SRs RIVER BEND 3.10-3 Amendment No. 81

Reactor Mode Switch Interlock Testing 3.10.2 3.10 SPECIAL OPERATIONS 3.10.2 Reactor Mode Switch Interlock Testingt LCO 3.10.2 The reactor mode switch position specified in Table 1.1-1 (Section 1.1, Definitions) for MODES 3, 4, and 5 may be changed to include the run, startup/hot standby, and refuel position, and operation considered not to be in MODE 1 or 2, to allow testing of instrumentation associated with the reactor mode switch interlock functions, provided:

a. All control rods remain fully inserted in core cells containing one or more fuel assemblies; and

b. No CORE ALTERATIONS are in progress.

APPLICABILITY: MODES 3 and 4 with the reactor mode switch in the run, startup/hot standby, or refuel position, MODE 5 with the reactor mode switch in the run or startup/hot standby position.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more of the A.1 Suspend CORE Immediately above requirements not ALTERATIONS except met. for control rod insertion.

AND A.2 Fully insert all 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months insertable control rods in core cells containing one or more fuel assemblies.

AND (continued)

RIVER BEND 3.10-4 Amendment No. 81

Reactor Mode Switch Interlock Testing 3.10.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.3.1 Place the reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months mode switch in the shutdown position.

OR A.3.2 -------- NOTE---------

Only applicable in MODE 5.

Place the reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months mode switch in the refuel position.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.2.1 Verify all control rods are fully inserted 12 hours0.5 days 0.0714 weeks 0.0164 months in core cells containing one or more fuel assemblies.

SR 3.10.2.2 Verify no CORE ALTERATIONS are in progress. 24 hours1 days 0.143 weeks 0.0329 months RIVER BEND 3.10-5 Amendment No. 81

Single Control Rod Withdrawal-Hot Shutdown 3.10.3 3.10 SPECIAL OPERATIONS 3.10.3 Single Control Rod Withdrawal -Hot Shutdown LCO 3.10.3 The reactor mode switch position specified in Table 1.1-1 for MODE 3 may be changed to include the refuel position, and operation considered not to be in MODE 2, to allow withdrawal of a single control rod, provided the following requirements are met:

a. LCO 3.9.2, "Refuel Position One-Rod-Out Interlock";

b. LCO 3.9.4, "Control Rod Position Indication";

c. All other control rods are fully inserted; and

d. 1. LCO 3.3.1.1, "Reactor Protection System (RPS)

Instrumentation," MODE 5 requirements for Functions I.a, 1.b, 8.a, 8.b, 11, and 12 of Table 3.3.1.1-1, and LCO 3.9.5, "Control Rod OPERABILITY-Refueling,"

OR

2. All other control rods in a five by five array centered on the control rod being withdrawn are disarmed at which time LCO 3.1.1, "SHUTDOWN MARGIN (SDM)," MODE 3 requirements may be changed to allow the single control rod withdrawn to be assumed to be the highest worth control rod.

APPLICABILITY: MODE 3 with the reactor mode switch in the refuel position.

RIVER BEND 3.10-6 Amendment No. 81

Single Control Rod Withdrawal -Hot Shutdown 3.10.3 ACTIONS Separate Condition entry is allowed for each requirement of the LCO.

CONDITION I REQUIRED ACTION COMPLETION TIME A. One or more of the A.1 -------- NOTES--------

above requirements not 1. Required Actions met. to fully insert all insertable control rods include placing the reactor mode switch in the shutdown position.

2. Only applicable if the requirement not met is a required LCO.

Enter the applicable Immediately Condition of the affected LCO.

OR A.2.1 Initiate action to Immediately fully insert all insertable control rods.

AND A.2.2 Place the reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months mode switch in the shutdown position.

____________________________________ A.________________________________________ a _______________________

RIVER BEND 3.10-7 Amendment No. 81

Single Control Rod Withdrawal -Hot Shutdown 3.10.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.3.1 Perform the applicable SRs for the required According to LCOs. the applicable SRs SR 3.10.3.2 -------------------NOTE--------------------

Not required to be met if SR 3.10.3.1 is satisfied for LCO 3.10.3.d.1 requirements.

Verify all control rods, other than the 24 hours1 days 0.143 weeks 0.0329 months control rod being withdrawn, in a five by five array centered on the control rod being withdrawn, are disarmed.

SR 3.10.3.3 Verify all control rods, other than the 24 hours1 days 0.143 weeks 0.0329 months control rod being withdrawn, are fully inserted.

RIVER BEND 3.10-8 Amendment No. 81

Single Control Rod Withdrawal-Cold Shutdown 3.10.4 3.10 SPECIAL OPERATIONS 3.10.4 Single Control Rod Withdrawal -Cold Shutdown LCO 3.10.4 The reactor mode switch position specified in Table 1.1-1 for MODE 4 may be changed to include the refuel position, and operation considered not to be in MODE 2, to allow withdrawal of a single control rod, and subsequent removal of the associated control rod drive (CRD) if desired, provided the following requirements are met:

a. All other control rods are fully inserted;

b. 1. LCO 3.9.2, "Refuel Position One-Rod-Out Interlock,"

and LCO 3.9.4, "Control Rod Position Indication,"

OR

2. A control rod withdrawal block is inserted; and

c. 1. LCO 3.3.1.1, "Reactor Protection System (RPS)

Instrumentation," MODE 5 requirements for Functions 1.a, 1.b, 8.a, 8.b, 11, and 12 of Table 3.3.1.1-1, and LCO 3.9.5, "Control Rod OPERABILITY-Refueling,"

OR

2. All other control rods in a five by five array centered on the control rod being withdrawn are disarmed at which time LCO 3.1.1, "SHUTDOWN MARGIN (SDM)," MODE 4 requirements may be changed to allow the single control rod withdrawn to be assumed to be the highest worth control rod.

APPLICABILITY: MODE 4 with the reactor mode switch in the refuel position.

RIVER BEND 3. 10-9 Amendment No. 81

Single Control Rod Withdrawal -Cold Shutdown 3.10.4 ACTIONS

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

Separate Condition entry is allowed for each requirement of the LCO.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more of the IA.1 -------- NOTES--------

above requirements not 1. Required Actions met with the affected to fully insert control rod all insertable insertable. control rods include placing the reactor mode switch in the shutdown position.

2. Only applicable if the requirement not met is a required LCO.

Enter the applicable Immediately Condition of the affected LCO.

OR A.2.1 Initiate action to Immediately fully insert all insertable control rods.

AND A.2.2 Place the reactor 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months mode switch in the shutdown position.

(continued)

RIVER BEND 3. 10-10 Amendment No. 81

Single Control Rod Withdrawal-Cold Shutdown 3.10.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One or more of the B.1 Suspend withdrawal of Immediately above requirements not the control rod and met with the affected removal of associated control rod not CRD.

insertable.

AND B.2.1 Initiate action to Immediately fully insert all control rods.

OR B.2.2 Initiate action to Immediately satisfy the requirements of this LCO.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.4.1 Perform the applicable SRs for the required According to LCOs. applicable SRs SR 3.10.4.2 -------------------NOTE--------------------

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 24 hours1 days 0.143 weeks 0.0329 months control rod being withdrawn, in a five by five array centered on the control rod being withdrawn, are disarmed.

(continued)

RIVER BEND 3. 10-11 Amendment No. 81

Single Control Rod Withdrawal -Cold Shutdown 3.10.4 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.10.4.3 Verify all control rods, other than the 24 hours1 days 0.143 weeks 0.0329 months control rod being withdrawn, are fully inserted.

SR 3.10.4.4 -------------------NOTE--------------------

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 24 hours1 days 0.143 weeks 0.0329 months inserted.

RIVER BEND 3.10-12 Amendment No. 81

Single CRD Removal -Refueling 3.10.5 3.10 SPECIAL OPERATIONS 3.10.5 Single Control Rod Drive (CRD) Removal -Refueling LCO 3.10.5 The requirements of LCO'3.3.1.1, "Reactor Protection System (RPS) Instrumentation"; LCO 3.3.8.2, "Reactor Protection System (RPS) Electric Power Monitoring"; LCO 3.9.1, "Refueling Equipment Interlocks"; LCO 3.9.2, "Refuel Position One-Rod-Out Interlock"; LCO 3.9.4, "Control Rod Position Indication"; and LCO 3.9.5, "Control Rod OPERABILITY-Refueling," may be suspended in MODE 5 to allow the removal of a single CRD associated with a control rod withdrawn from a core cell containing one or more fuel assemblies, provided the following requirements are met:

a. All other control rods are fully inserted;

b. All other control rods in a five by five array centered on the withdrawn control rod are disarmed;

c. A control rod withdrawal block is inserted and LCO 3.1.1, "SHUTDOWN MARGIN (SDM)," MODE 5 requirements may be changed to allow the single control rod withdrawn to be assumed to be the highest worth control rod; and

d. No other CORE ALTERATIONS are in progress.

APPLICABILITY: MODE 5 with LCO 3.9.5 not met.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more of the A.1 Suspend removal of Immediately above requirements not the CRD.mechanism.

met.

AND (continued)

RIVER BEND 3.10-13 Amendment No. 81

Single CRD Removal -Refueling 3.10.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.1 Initiate action to Immediately fully insert all control rods.

OR A.2.2 Initiate action to Immediately satisfy the requirements of this LCO.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.5.1 Verify all controls rods, other than the 24 hours1 days 0.143 weeks 0.0329 months control rod withdrawn for the removal of the associated CRD, are fully inserted.

SR 3.10.5.2 Verify all control rods, other than the 24 hours1 days 0.143 weeks 0.0329 months 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.

SR 3.10.5.3 Verify a control rod withdrawal block is 24 hours1 days 0.143 weeks 0.0329 months inserted.

(continued)

RIVER BEND 3.10-14 Amendment No. 81

Single CRD Removal -Refueling 3.10.5 SURVEILLANCE REQUIREMENTS (continued) .

SURVEILLANCE FREQUENCY SR 3.10.5.4 Perform SR 3.1.1.1. According to SR 3.1.1.1 SR 3.10.5.5 Verify no CORE ALTERATIONS are in progress. 24 hours1 days 0.143 weeks 0.0329 months RIVER BEND 3. 10- 15 Amendment No. 81

Multiple Control Rod Withdrawal-Refueling 3.10.6 3.10 SPECIAL OPERATIONS 3.10.6 Multiple Control Rod Withdrawal -Refueling LCO 3.10.6 The requirements of LCO 3.9.3, "Control Rod Position";

ICO 3.9.4, "Control Rod Position Indication"; and LCO 3.9.5, "Control Rod OPERABILITY-Refueling," may be suspended, and the "full in' position indicators may be bypassed for any number of control rods in MODE 5, to allow withdrawal of these control rods, removal of associated control rod drives (CRDs), or both, provided the following requirements are met:

a. The four fuel assemblies are removed from the core cells associated with each control rod or CRD to be removed;

b. All other control rods in core cells containing one or more fuel assemblies are fully inserted; and

c. Fuel assemblies shall only be loaded in compliance with an approved spiral reload sequence.

APPLICABILITY: MODE 5 with LCO 3.9.3, LCO 3.9.4, or LCO 3.9.5 not met.

ACTIONS -

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more of the A.1 Suspend withdrawal of Immediately above requirements not control rods and met. removal of associated CRDs.

AND A.2 Suspend loading fuel Immediately assemblies.

AND (continued)

RIVER BEND 3. 10- 16 Amendment No. 81

Multiple Control Rod Withdrawal -Refueling 3.10.6 ACTIONS -

CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.3.1 Initiate action to Immediately fully insert all control rods in core cells containing one or more fuel assemblies.

OR A.3.2 Initiate action to Immediately satisfy the requirements of this LCO.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.6.1 Verify the four fuel assemblies are removed 24 hours1 days 0.143 weeks 0.0329 months from core cells associated with each control rod or CRD removed.

SR 3.10.6.2 Verify all other control rods in core cells 24 hours1 days 0.143 weeks 0.0329 months containing one or more fuel assemblies are fully inserted.

SR 3.10.6.3 -------------------NOTE--------------------

Only required to be met during fuel loading.

Verify fuel assemblies being loaded are in 24 hours1 days 0.143 weeks 0.0329 months compliance with an approved spiral reload sequence.

RIVER BEND 3.10-17 Amendment No. 81

Control Rod Testing-Operating 3.10.7 3.10 SPECIAL OPERATIONS 3.10.7 Control Rod Testing-Operating LCO 3.10.7 The requirements of LCO 3.1.6, "Control Rod Pattern," may be suspended and control rods bypassed in the Rod Action Control System as allowed by SR 3.3.2.1.9, to allow performance of SDM demonstrations, control rod scram time testing, and control rod friction testing, provided conformance to the approved control rod sequence for the specified test is verified by a second licensed operator or other qualified member of the technical staff.

APPLICABILITY: MODES 1 and 2 with LCO 3.1.6 not met.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of the A.1 Suspend performance Immediately LCO not met. of the test and exception to LCO 3.1.6.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.7.1 Verify movement of control rods is in During control compliance with the approved control rod rod movement sequence for the specified test by a second licensed operator or other qualified member of the technical staff.

RIVER BEND 3.10-18 Amendment No. 81

SDM Test - Refueling 3.10.8 3.10 SPECIAL OPERATIONS 3.10.8 SHUTDOWN MARGIN (SDM) Test -Refueling LCO 3.10.8 The reactor mode switch position specified in Table 1.1-1 for MODE 5 may-be changed to include the startup/hot standby position, and operation considered not to be in MODE 2. to allow SDM testing, provided the following requirements are met:

a. LCO 3.3.1.1. "Reactor Protection System (RPS)

Instrumentation." MODE 2 requirements for Function 2.a and 2.d of Table 3.3.1.1-1:

b. 1. LCO 3.3.2.1. "Control Rod Block Instrumentation." MODE 2 requirements for Function 1.b of Table 3.3.2.1-1.

OR

2. Conformance to the approved control rod sequence for the SDM test is verified by a second licensed operator or other qualified member of the technical staff:

c. Each withdrawn control-rod shall be coupled to the associated CRD:

d. All control rod withdrawals during out of sequence control rod moves shall be made in single notch withdrawal mode:

e. No other CORE ALTERATIONS are in progress: and I f. CRD charging water header pressure 2 1540 psig.

APPLICABILITY: MODE 5 with the reactor mode switch in startup/hot standby position.

RIVER BEND 3.10-19 Amendment No. 8w-. 114 OCT 0 6 2MDD

SDM Test-Refueling 3.10.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME

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

Separate Condition entry Inoperable control rods may is allowed for each be bypassed in RACS in control rod. accordance with SR 3.3.2.1.9, if required, to allow insertion of inoperable A. One control rod not control rod and continued coupled to its operation.

associated CRD. --

A.1 Fully insert 3 hours0.125 days 0.0179 weeks 0.00411 months inoperable control rod.

AND A.2 Disarm the associated 4 hours0.167 days 0.0238 weeks 0.00548 months CRD.

B. One or more of the B.1 Place the reactor Immediately above requirements not mode switch in the met for reasons other shutdown or refuel than Condition A. position.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.iO.8.1 Perform the MODE 2 applicable SRs for According to LCO 3.3.1.1, Functions 2.a and 2.d of the applicable Table 3.3.1.1-1. SRs (continued)

RIVER BEND 3.10-20 Amendment No. 81

SDM Test-Refueling 3.10.8 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.10.8.2 -------------------NOTE--------------------

Not required to be met if SR 3.10.8.3 satisfied.

Perform the MODE 2 applicable SRs for According to LCO 3.3.2.1, Function 1.b of the applicable Table 3.3.2.1-1. SRs SR 3.10.8.3 -------------------NOTE--------------------

Not required to be met if SR 3.10.8.2 satisfied.

Verify movement of control rods is in During control compliance with the approved control rod rod movement sequence for the SDM test by a second licensed operator or other qualified member of the technical staff.

SR 3.10.8.4 Verify no other CORE ALTERATIONS are in 12 hours0.5 days 0.0714 weeks 0.0164 months progress.

(continued)

RIVER BEND 3.10-21 Amendment No. 81

SDM Test - Refueling 3.10.8 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.10.8.5 Verify each withdrawn control rod does not go Each time the to the withdrawn overtravel position. control rod is withdrawn to "full out" position AND Prior to satisfying LCO 3.10.8.c requirement after work on control rod or CRD System that could affect coupling SR 3.10.8.6 Verify CRD charging water header pressure 7 days I

1540 psig.

RIVER BEND 3.10-22 Amendment No. 8i-, 114 OCT 0 6 2LrO3

Design Features 4.0 DESIGN FEATURES 4.1 Site Location The River Bend Station is located in West Feliciana Parish, Louisiana, on the east bank of the Mississippi River approximately 24 miles north-northwest of Baton Rouge (city center), Louisiana.

The site comprises approximately 3342 acres. The exclusion area boundary shall have a radius of 3000 feet from the centerline of the reactor.

4.2 Reactor Core 4.2.1 Fuel Assemblies The reactor shall contain 624 fuel assemblies. Each assembly shall consist of a matrix of Zircaloy or ZIRLO clad fuel rods with an initial composition of natural or slightly enriched uranium dioxide (UO ) as fuel material. Limited substitutions of zirconium alloy or stainless steel filler rods for fuel rods, in accordance with approved applications of fuel rod configurations, may be used. Fuel assemblies shall be limited to those fuel designs that have been analyzed with applicable NRC staff approved

./ codes and methods and shown by tests or analyses to comply with all safety design bases. A limited number of lead test assemblies that have not completed representative testing may be placed in nonlimiting core regions.

4.2.2 Control Rod Assemblies The reactor core shall contain 145 cruciform shaped control rod assemblies. The control material shall be boron carbide or hafnium metal, or both.

4.3 Fuel Storage 4.3.1 Criticality 4.3.1.1 The spent fuel storage racks are designed and shall be maintained with:

a. keff s 0.95 if fully flooded with unborated water, which includes an allowance for uncertainties as described in Section 9.1 of the USAR;

-' (continued)

RIVER BEND 4.0-1 Amendment No. 81

Design Features 4.0 4.0 DESIGN FEATURES 4.3.1.1 (continued)

b. A nominal fuel assembly center to center storage spacing of 7 inches within rows and 12.25 inches between rows in the low density storage racks in the upper containment pool: and

c. A nominal fuel assembly center to center storage spacing of 6.28 inches within a rack and 8.5 inches between cell centers of adjacent racks in the high density storage racks in the spent fuel storage facility in the Fuel Building.

4.3.1.2 The new fuel storage racks are designed and shall be maintained with:

a. keff 5 0.95 if fully flooded with unborated water. which includes an allowance for uncertainties as described in Section 9.1.1 of the USAR:

b. A nominal fuel assembly center to center storage spacing of 7 inches within rows and 12.25 inches between rows in the new fuel storage racks.

4.3.2 Drainage The spent fuel storage pool is designed and shall be maintained to prevent inadvertent draining of the pool below elevation 95 ft.

4.3.3 Capacitv 4.3.3.1 The spent fuel storage pool is designed and shall be maintained with a storage capacity limited to no more I than 3104 fuel assemblies.

4.3.3.2 No more than 200 fuel assemblies may be stored in the upper containment pool.

RIVER BEND 4.0-2 Amendment No. 8i-. 123 t10V 1 C 2D11

Responsibility 5.1 5.0 ADMINISTRATIVE CONTROLS 5.1 Responsibility 5.1.1 The-plant manager shall be responsible for overall unit operation and shall delegate in writing the succession to this responsibility during his absence.

The plant manager, or his designee, shall approve, prior to implementation, each proposed test, experiment or modification to systems or equipment that affect nuclear safety.

5.1.2 The shift superintendent shall be responsible for the control room command function. During any absence of the shift superintendent from the control room while the unit is in MODE 1, 2, or 3, an individual with an active Senior Reactor Operator (SRO) license shall be designated to assume the control room command function.

During any absence of the shift superintendent from the control room while the unit is in MODE 4 or 5, an individual with an active SRO license or Reactor Operator (RO) license shall be designated to assume the control room command function.

RIVER BEND 5.0-1 Amendment No. 81

Organization 5.2 5.0 ADMINISTRATIVE CONTROLS 5.2 Organization 5.2.1 Onsite and Offsite Organizations Onsite and offsite organizations shall be established for unit operation and corporate management, respectively. The onsite and offsite organizations shall include the positions for activities affecting safety of the nuclear power plant.

a. Lines of authority, responsibility, and communication shall be defined and established throughout highest management levels, intermediate levels, and all operating organization positions. These relationships shall be documented and updated, as appropriate, in organization charts, functional descriptions of departmental responsibilities and relationships, and job descriptions for key personnel positions, or in equivalent forms of documentation. These requirements, including the plant specific titles of those personnel fulfilling the responsibilities of the positions delineated in these Technical Specifications shall be documented in the USAR;

b. The plant manager shall be responsible for overall safe operation of the plant and shall have control over those onsite activities necessary for safe operation and maintenance of the plant;

c. A specified corporate executive shall have corporate responsibility for overall plant nuclear safety and shall take any measures needed to ensure acceptable performance of the staff in operating, maintaining, and providing technical support to the plant to ensure nuclear safety; and

d. The individuals who train the operating staff, carry out health physics, or perform quality assurance functions may report to the appropriate onsite manager; however, these individuals shall have sufficient organizational freedom to ensure their independence from operating pressures.

5.2.2 Unit Staff The unit staff organization shall include the following:

a. A non-licensed operator shall be on site when fuel is in the reactor and an additional non-licensed operator shall be on site while the unit is in MODE 1, 2, or 3.

(continued)

RIVER BEND 5.0-2 Amendment No. 81

Organization 5.2 5.2 Organization 5.2.2 Unit Staff (continued)

b. At least one licensed Reactor Operator (RO) shall be present in the control room when fuel is in the reactor. In addition, while the unit is in MODE 1, 2, or 3, at least one licensed Senior Reactor Operator (SRO) shall be present in the control room.

c. Shift crew composition may be one less than the minimum requirements of 10CFR50.54(m)(2)(i) and specifications 5.2.2.a and 5.2.2.g for a period of time not to exceed 2 hours0.0833 days 0.0119 weeks 0.00274 months in order to accommodate unexpected absence of on-duty shift crew members provided immediate action is taken to restore the shift crew composition to within the minimum requirements.

d. A health physics technician shall be on site when fuel is in the reactor.

The position may be vacant for not more than 2 hours0.0833 days 0.0119 weeks 0.00274 months , in order to provide for unexpected absence, provided immediate action is taken to fill the required position.

e. DELETED (continued)

RIVER BEND 5.0-3 Amendment No. ~, 164

Organization 5.2 5.2 Organization 5.2.2 Unit Staff (continued)

f. The operations manager or at least one operations middle manager shall hold an SRO license.

g. When in MODES 1, 2, or 3 an individual shall provide advisory technical support to the unit operations crew in the areas of thermal hydraulics, reactor engineering, and plant analysis with regard to the safe operations of the unit. This individual shall meet the qualifications specified by ANSIfANS 3.1-1993 as endorsed by RG 1.8, Rev. 3,2000.

RIVER BEND 5.0-4 Amendment No. 81 164,178

Unit Staff Qualifications 5.3 5.0 ADMINISTRATIVE CONTROLS 5.3 Unit Staff Qualifications 5.3.1 Each member of the unit staff shall meet or exceed the minimum qualifications of ANSI/ANS 3.1-1978 for comparable positions with exceptions specified in the Entergy Quality Assurance Program Manual (QAPM).

5.3.2 For the purpose of 10 CFR 55.4, a licensed Senior Reactor Operator (SRO) and a licensed Reactor Operator (RO) are those individuals who, in addition to meeting the requirements of Specification 5.3.1, perform the functions described in 10 CFR 50.54(m).

RIVER BEND 5.0-5 Amendment No. 84, 178

Procedures 5.4 5.0 ADMINISTRATIVE CONTROLS A/

5.4 Procedures 5.4.1 Written procedures shall be established, implemented, and maintained covering the following activities:

a. The applicable procedures recommended in Regulatory Guide 1.33, Revision 2, Appendix A, February 1978;

b. The emergency operating procedures required to implement the requirements of NUREG-0737 and NUREG-0737, Supplement 1;

c. Quality assurance for effluent and environmental monitoring;

d. Fire protection program implementation; and

e. All programs specified in Specification 5.5.

RIVER BEND 5.0-6 Amendment No. 81

Programs and Manuals 5.5 5.0 ADMINISTRATIVE CONTROLS 5.5 Programs and Manuals The following programs and manuals shall be established, implemented, and maintained.

5.5.1 Offsite Dose Calculation Manual (ODCM)

a. The ODCM shall contain the methodology and parameters used in the calculation of offsite doses resulting from radioactive gaseous and liquid effluents, in the calculation of gaseous and liquid effluent monitoring alarm and trip setpoints, and in the conduct of the radiological environmental monitoring program; and

b. The ODCM shall also contain the radioactive effluent controls and radiological environmental monitoring programs and descriptions of the information that should be included in the Annual Radiological Environmental Operating, and Radioactive Effluent Release report.

Licensee initiated changes to the ODCM:

a. Shall be documented and records of reviews performed shall be retained. This documentation shall contain:

1. sufficient information to support the change(s) together with the appropriate analyses or evaluations justifying the change(s), and

2. a determination that the change(s) maintain the levels of radioactive effluent control required by 10 CFR 20.1302, 40 CFR 190, 10 CFR 50.36a, and 10 CFR 50, Appendix I, and not adversely impact the accuracy or reliability of effluent, dose, or setpoint calculations;

b. Shall become effective after review and acceptance, including approval of the radiation protection manager; and (continued)

RIVER BEND 5.0-7 Amendment No. 81

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.1 Offsite Dose Calculation Manual (ODCM) (continued)

c. Shall be submitted to the NRC in the form of a complete, legible copy of the entire ODCM as a part of, or concurrent with, the Radioactive Effluent Release Report for the period of the report in which any change in the ODCM was made. Each change shall be identified by markings in the margin of the affected pages, clearly indicating the area of the page that was changed, and shall indicate the date (i.e., month and year) the change was implemented.

5.5.2 Primary Coolant Sources Outside Containment This program provides controls to minimize leakage from those portions of systems outside containment that could contain highly radioactive fluids during a serious transient or accident to levels as low a practicable. The systems include the Low Pressure Core Spray, High Pressure Core Spray, Residual Heat Removal, Reactor Core Isolation Cooling, and process sampling (until such time as a modification eliminates the PASS penetration as a potential leakage path). I The program shall include the following:

a. Preventive maintenance and periodic visual inspection requirements; and

b. Integrated leak test requirements for each system at refueling cycle intervals or less.

5.5.3 Deleted I (Continued)

RIVER BEND 5.0-8 Amendment No. 61 119,134 JON 2 3 .

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.4 Radioactive Effluent Controls Program This program conforms to 10 CFR 50.36a for the control of radioactive effluents and for maintaining the doses to members of the public from radioactive effluents as low as reasonably achievable. The program shall be contained in the ODCM, shall be implemented by procedures, and shall include remedial actions to be taken whenever the program limits are exceeded. The program shall include the following elements:

a. Limitations on the functional capability of radioactive liquid and gaseous monitoring instrumentation including surveillance tests and setpoint determination in accordance with the methodology in the ODCM;

b. Limitations on the concentrations of radioactive material released in liquid effluents to unrestricted areas, conforming to ten times the concentration values in 10 CFR 20, Appendix B, Table 2, Column 2;

c. Monitoring, sampling, and analysis of radioactive liquid and gaseous effluents in accordance with 10 CFR 20.1302 and with the methodology and parameters in the ODCM;

d. Limitations on the annual and quarterly doses or dose commitment to a member of the public from radioactive materials in liquid effluents released from the unit to unrestricted areas, conforming to 10 CFR 50, Appendix I;

e. Determination of cumulative and projected dose contributions from radioactive effluents for the current calendar quarter and current calendar year in accordance with the methodology and parameters in the ODCM at least every 31 days;

f. Limitations on the functional capability and use of the liquid and gaseous effluent treatment systems to ensure that appropriate portions of these systems are used to reduce releases of radioactivity when the projected doses in a period of 31 days would exceed 2% of the guidelines for the annual dose or dose commitment, conforming to 10 CFR 50, Appendix I; (continued)

RIVER BEND 5.0-9 Amendment No. 81

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.4 Radioactive Effluent Controls Program (continued)

g. Limitations on the dose rate resulting from radioactive material released in gaseous effluents to areas beyond the site boundary:

1. for noble gases: s 500 mrem/yr to the total body and s 3000 mrem/yr to the skin, and

2. for iodine-131, for iodine-133, for tritium, and for all radionuclides in particulate form with half-lives> 8 days: s 1500 mrem/yr to any organ;

h. Limitations on the annual and quarterly air doses resulting from noble gases released in gaseous effluents from the unit to areas beyond the site boundary, conforming to 10 CFR 50, Appendix I;

i. Limitations on the annual and quarterly doses to a member of the public from iodine-131, iodine-133, tritium, and all radionuclides in particulate form with half lives> 8 days in gaseous effluents released from the unit to areas beyond the site boundary, conforming to 10 CFR 50, Appendix I; and

j. Limitations on the annual dose or dose commitment to any member of the public due to releases of radioactivity and to radiation from uranium fuel cycle sources, conforming to 40 CFR 190.

5.5.5 Component Cyclic or Transient Limit This program provides controls to track the cyclic and transient occurrences identified on USAR Table 3.98-22 to ensure that the reactor vessel is maintained within the design limits.

5.5.6 Inservice Testing Program This program provides controls for inservice testing of ASME Code Class 1, 2, and 3 components including applicable supports. The program shall include the following:

a. Testing frequencies applicable to the ASME Code for Operations and Maintenance of Nuclear Power Plants (ASME OM Code) and applicable Addenda as follows:

(continued)

RIVER BEND 5.0-10 Amendment No. 84, 167

Programs and Manuals 5.5 5.5 Programs and Manuals ASME OM Code and applicable Addenda terminology for Required frequencies inservice testing for performing inservice activities testing activities Weekly At least once per 7 days Monthly At least once per 31 days Quarterly or every 3 months At least once per 92 days Semiannually or every 6 months At least once per 184 days Every 9 months At least once per 276 days Yearly or annually At least once per 366 days Biennially or every 2 years 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 Inservice 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.

5.5.7 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 of 24 months.

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 Flowrate SGTS 12,500 cfm FBVS 10,000 cfm CRFAS 4,000 cfm (continued)

RIVER BEND 5.0-11 Amendment No. 81 165 167, 168

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.7 Ventilation Filter Testing Program (VFTP) (continued)

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 Flowrate SGTS 12,500 cfm FBVS 10,000 cfm CRFAS 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 Penetration SGTS 5.0% 95%*

FBVS 5.0% 95%

CRFAS 1.0% 95%

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 N51 0-1989 at the system flowrate specified below +/- 10%:

ESF Ventilation System Delta P Flowrate SGTS * <8"WG 12,500 cfm FBVS <8"WG 10,000 cfm CRFAS <8"WG 4,000 cfm (continued)

RIVER BEND 5.0-12 Amendment No. B1 115 1a2 165, 183

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.7 Ventilation Filter Testing Program (VFTP) (continued)

e. Deleted The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the VFTP test frequencies.

5.5.8 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.

5.5.9 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)

RIVER BEND 5.0-13 Amendment No. 81 159; 183

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.9 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/l when tested every 31 days in accordance with ASTM D-2276, Method A-2 or A-3.

5.5.10 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)

RIVER BEND 5.0-14 Amendment No. 81

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.10 Safety Function Determination Program (SFDP) (continued)

c. Provisions to ensure that an inoperable supported system's Completion Time is not inappropriately extended as a result of multiple support system inoperabilities; and

d. Other appropriate limitations and remedial or compensatory actions.

A loss of safety function exists when, assuming no concurrent single failure, a safety function assumed in the accident analysis cannot be performed. For the purpose of this program, a loss of safety function may exist when a support system is inoperable, and:

a. A required system redundant to system(s) supported by the inoperable support system is also inoperable; or

b. A required system redundant to system(s) in turn supported by the inoperable supported system is also inoperable; or

c. A required system redundant to support system(s) for the supported systems (a)and (b) above is also inoperable.

The SFDP identifies where a loss of safety function exists. If a loss of safety function is determined to exist by this program, the appropriate Conditions and Required Actions of the LCO in which the loss of safety function exists are required to be entered.

5.5.11 Technical Specifications (TS) Bases Control Program This program provides a means for processing changes to the Bases of these Technical Specifications.

a. Changes to the Bases of the TS shall be made under appropriate administrative controls and reviews.

b. Licensees may make changes to Bases without prior NRC approval provided the changes do not involve either of the following:

1. A change in the TS incorporated in the license; or

2. A change to the USAR or Bases that involves an unreviewed safety question as defined in 10 CFR 50.59.

(continued)

RIVER BEND 5.0-15 Amendment No. 81

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.11 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).

5.5.12 DELETED 5.5.13 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.

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.

5.5.14 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 (continued)

RIVER BEND 5.0-16 Amendment No. 81 84 95 131 132 150 154 4-ea, 191

Programs and Manuals 5.5 5.5.14 Control Room Envelope Habitability Program (continued)

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 (DBA) 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 testi ng specified at a freq uency of 18 months is required at a frequency of 24 months.

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 of 24 months on a STAGGERED TEST BASIS. The results shall be trended and used as part of the 24 month assessment of the CRE boundary.

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.

RIVER BEND 5.0-16a Amendment No. +a4, 168

Reporting Requirements 5.6 5.0 ADMINISTRATIVE CONTROLS 5.6 Reporting Requirements The following reports shall be submitted in accordance with 10 CFR 50.4.

5.6.1 Deleted 5.6.2 Annual Radiological Environmental Operating Report The Annual Radiological Environmental Operating Report covering the operation of the unit during the previous calendar year shall be submitted by May 1 of each year. The report shall include summaries, interpretations, and analyses of trends of the results of the Radiological Environmental Monitoring Program for the reporting period. The material provided shall be consistent with the objectives outlined in the Offsite Dose Calculation Manual (ODCM), and in 10 CFR 50, Appendix I, Sections IV.B.2, IV.B.3, and IV.C.

The Annual Radiological Environmental Operating Report shall include the results of analyses of all radiological environmental samples and of all environmental radiation measurements taken during the period pursuant to the locations specified in the table and figures in the ODCM, as well as summarized and tabulated results of these analyses and measurements in the format of the table in the Radiological Assessment Branch Technical Position, Revision 1, November 1979. In the event that some individual (continued)

RIVER BEND 5.0-1 7 Amendment No. 84, 145

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.2 Annual Radiological Environmental Operating Report (continued) results are not,available for inclusion with the report, the report shall be submitted noting and explaining the reasons for the missing results. The missing data shall be submitted in a supplementary report as soon as possible.

5.6.3 Radioactive Effluent Release Report The Radioactive Effluent Release Report covering the operation of the unit during the previous calendar year shall be submitted by May 1 of each year. The report shall include a summary of the quantities of radioactive liquid and gaseous effluents and solid waste released from the unit. The material provided shall be consistent with the objectives outlined in the ODCM and process control program and in conformance with 10 CFR 50.36a and 10 CFR 50, Appendix I, Section IV.B.1.

5.6.4 Deleted 5.6.5 CORE OPERATING LIMITS REPORT (COLR)

a. Core operating limits shall be established prior to each reload cycle, or prior to any remaining portion of a reload cycle, and shall be documented in the COLR for the following:

1) LCO 3.2.1, Average Planar Linear Heat Generation Rate (APLHGR),

2) LCO 3.2.2, Minimum Critical Power Ratio (MCPR)(including power and flow dependent limits).

3) LCO 3.2.3, Linear Heat Generation Rate (LHGR)(including power and flow dependent limits).

4) LCO 3.2.4, Fraction of Core Boiling Boundary (FCBB)

5) LCO 3.3.1.1, RPS Instrumentation (RPS), Function 2.b

6) LCO 3.3.1.3, Periodic Based Detection System (PBDS)

b. The analytical methods used to determine the core operating limits shall be those previously reviewed and approved by the NRC, specifically those described in the following documents.

(continued)

RIVER BEND 5.0-18 Amendment No. 81 100 106 122 135,145

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.5 CORE OPERATING LIMITS REPORT (COLR) (continued)

1) XN-NF-81-58(P)(A), "RODEX2 Fuel Rod Thermal-Mechanical Response Evaluation Model", Exxon Nuclear Company, Richland, WA.

2) XN-NF-85-67(P)(A), "Generic Mechanical Design for Exxon Nuclear Jet Pump BWR Reload Fuel", Exxon Nuclear Company, Richland, WA.

3) EMF-85-74(P) Supplement 1 (P)(A) and Supplement 2(P)(A),

"RODEX2A (BWR) Fuel Rod Thermal-Mechanical Evaluation Model". Siemens Power Corporation, Richland, WA.

4) ANF-89-98(P)(A), "Generic Mechanical Design Criteria for BWR Fuel Designs", Advanced Nuclear Fuels Corporation, Richland, WA.

5) XN-NF-80-19(P)(A) Volume 1. "Exxon Nuclear Methodology for Boiling Water Reactors - Neutronic Methods for Design and Analysis", Exxon Nuclear Company, Richland. WA.

6) XN-NF-80-19(P)(A) Volume 4, "Exxon Nuclear Methodology for Boiling Water Reactors: Application for the ENC Methodology to BWR Reloads", Exxon Nuclear Company, Richland, WA.

7) EMF-2158(P)(A), "Siemens Power Corporation Methodology for Boiling Water Reactors: Evaluation and Validation of CASMO-4/MICROBURN-B2". Siemens Power Corporation, Richland, WA.

8) XN-NF-80-19(P)(A) Volume 3, "Exxon Nuclear Methodology for Boiling Water Reactors, THERMEX: Thermal Limits Methodology Summary Description", Exxon Nuclear Company, Richland, WA.

9) XN-NF-84-105(P)(A), Volume 1, "XCOBRA-T: A Computer Code for BWR Transient Thermal-Hydraulic Core Analysis", Exxon Nuclear Company, Richland, WA.

10) ANF-524(P)(A), "ANF Critical Power Methodology for Boiling Water Reactors", Advanced Nuclear Fuels Corporation, Richland, WA.

11) ANF-913(P)(A) Volume 1, "CONTRANSA2: A Computer Program for Boiling Water Reactor Transient Analysis", Advanced Nuclear Fuels Corporation, Richland, WA.

RIVER BEND 5.0-18a Amendment No.122

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.5 CORE OPERATING LIMITS REPORT (COLR) (continued)

12) XN-NF-825(P)(A), Supplement 2, BWR/6 Generic Rod Withdrawal Error Analysis, MCPRp for Plant Operations within the Extended Operation Domain, Exxon Nuclear Company, Richland, WA.

13) ANF-1358(P)(A), The Loss of Feedwater Heating Transient in Boiling Water Reactors, Advanced Nuclear Fuels Corporation, Richland, WA.

14) EMF-1997(P)(A), ANFB-10 Critical Power Correlation, Siemens Power Corporation, Richland, WA.

15) EMF-1997(P) Supplement 1 (P)(A), ANFB-10 Critical Power Correlation High Local Peaking Results, Siemens Power Corporation, Richland, WA.

16) EMF-2209(P)(A), SPCB Critical Power Correlation, Siemens Power Corporation, Richland, WA.

17) EMF-2245(P(A), Application of Siemens Power Corporations Critical Power Correlations to Co-Resident Fuel, Siemens Power Corporation, Richland, WA.

18) EMF-2361(P)(A), EXEM BWR-2000 ECCS Evaluation Model, Framatome ANP Richland, Inc.

19) Deleted

20) Deleted

21) Deleted

22) EMF-CC-074(P)(A), Volume 4, BWR Stability Analysis Assessment of STAIF with Input from MICROBURN-B2, Siemens Power Corporation, Richland, WA.

23) EMF-2292(P)(A), ATRIUM-10 Appendix K Spray Heat Transfer Coefficients, Siemens Power Corporation, Richland, WA.

RIVER BEND 5.0-18b Amendment No.

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.5 CORE OPERATING LIMITS REPORT (COLR) (continued)

24) NEDE-24011-P-A, uGeneral Electric Standard Application for Reactor Fuel (GESTAR-II)".

25) NEDC-33383P, "GEXL97 Correlation Applicable to ATRIUM-10 Fuel," Global Nuclear Fuel.

c. The core operating limits shall be determined such that all applicable limits (e.g., fuel thermal mechanical limits, core thermal hydraulic limits, Emergency Core Cooling Systems (ECCS) limits, nuclear limits such as SDM, transient analysis limits, and accident analysis limits) of the safety analysis are met.

d. The COLR, including any midcycle revisions or supplements, shall be provided upon issuance for each reload cycle to the NRC.

RIVER BEND 5.0-19 Amendment No. 81 9699 100 105 106

~, 166

High Radiation Area 5.7 5.0 ADMINISTRATIVE CONTROLS 5.7 High Radiation Area 5.7.1 Pursuant to 10 CFR 20, paragraph 20.1601(c), in lieu of the requirements of 10 CFR 20.1601(a), each high radiation area, as defined in 10 CFR 20, in which the intensity of radiation is

> 100 mrem/hr but < 1000 mrem/hr, shall be barricaded and conspicuously posted as a high radiation area and entrance thereto shall be controlled by requiring issuance of a Radiation Work Permit (RWP). Individuals qualified in radiation protection procedures (e.g., health physics technician) or personnel continuously escorted by such individuals may be exempt from the RWP issuance requirement during the performance of their assigned duties in high radiation areas with exposure rates s 1000 mrem/hr, provided they are otherwise following plant radiation protection procedures for entry into such high radiation areas.

Any individual or group of individuals permitted to enter such areas shall be provided with or accompanied by one or more of the following:

a. A radiation monitoring device that continuously indicates the radiation dose rate in the area. I

b. A radiation monitoring device that continuously integrates the radiation dose rate in the area and alarms when a preset integrated dose is received. Entry into such areas with this monitoring device may be made after the dose rate levels in the area have been established and personnel are aware of them.

c. An individual qualified in radiation protection procedures with a radiation dose rate monitoring device, who is responsible for providing positive control over the activities within the area and shall perform periodic radiation surveillance at the frequency specified by the health physics supervision in the RWP.

5.7.2 In addition to the requirements of Specification 5.7.1, areas with radiation levels - 1000 mrem/hr shall be provided with locked or continuously guarded doors to prevent unauthorized entry and the keys shall be maintained under the administrative control of the shift supervisor on duty or health physics supervision. Doors shall remain locked except during periods of access by personnel under an approved RWP that shall specify the dose rate levels in (continued)

RIVER BEND 5.0-20 Amendment No. 81

High Radiation Area 5.7 5.7 High Radiation Area Q-i- 5.7.2 (continued) the immediate work areas and the maximum allowable stay times for individuals in those areas. In lieu of the stay time specification of the RWP, direct or remote (such as closed circuit TV cameras) continuous surveillance may be made-by personnel qualified in radiation protection procedures to provide positive exposure control over the activities being performed within the area.

5.7.3 In addition to the requirements of Specification 5.7.1, for individual high radiation areas with radiation levels of 2 1000 mrem/hr, accessible to personnel, that are located within large areas such as reactor containment, where no enclosure exists I for purposes of locking, or that is not continuously guarded, and where no enclosure can be reasonably constructed around the individual area, that individual area shall be barricaded and conspicuously posted, and a flashing light shall be activated as a warning device.

RIVER BEND 5.0-21 Amendment No. 81,95 AUG 2 6 1997

APPENDIX B TO FACILITY OPERATING LICENSE NO. NPF-47 RIVER BEND STATION UNIT I ENTERGY OPERATIONS, INC.

DOCKET NO. 50-458 ENVIRONMENTAL PROTECTION PLAN (NONRADIOLOGICAL)

Amendment No. 79 138

RIVER BEND STATION UNIT 1 ENVIRONMENTAL PROTECTION PLAN (NONRADIOLOGICAL)

TABLE OF CONTENTS Section Page 1.0 Objectives of the Environmental Protection Plan ................................................. 1-1 2.0 Environmental Protection Issues ........................................................ 2-1 2.1 Aquatic Issues ........................................................ 2-1 2.2 Terrestrial Issues ........................................................ 2-1 2.3 Noise Issues ........................................................ 2-1 3.0 Consistency Requirements ........................................................ 3-1 3.1 Plant Design and Operation ........................................................ 3-1 3.2 Reporting Related to the NPDES or LPDES Permit and State Certifications ....... 3-2 3.3 Changes Required for Compliance with Other Environmental Regulations .......... 3-2 4.0 Environmental Conditions .................................. : 4-1 4.1 Unusual or Important Environmental Events ................................. 4-1 4.2 Environmental Monitoring ................................. 4-1 5.0 Administrative Procedures ................................. 5-1 5.1 Review and Audit ................................. 5-1 5.2 Records Retention ................................. 5-1 5.3 Changes InEnvironmental Protection Plan ................................. 5-1 5.4 Plant Reporting Requirements ................................. 5-1 Amendment No. 138

1.0 Objectives of the Environmental Protection Plan The Environmental Protection Plan (EPP) is to provide for protection of nonradiological environmental values during operation of the nuclear facility. The principal objectives of the EPP are as follows:

(1) Verify that the facility Is operated in an environmentally acceptable manner, as established by the Final Environmental Statement - Operating Licensing Stage (FES-OL) and other NRC environmental Impact assessments.

(2) Coordinate NRC requirements and maintain consistency with other Federal, State and local requirements for environmental protection.

(3) Keep NRC Informed of the environmental effects of facility operation and of actions taken to control those effects.

Environmental concerns identified in the FES-OL which relate to water quality matters are regulated by way of the licensee's NPDES or LPDES permit.

1-? Amendment No. 138

2.0 Environmental Protecti6n Issues In the FES-OL dated January 1985, the staff considered the environmental impacts associated with the operation of the River Bend Station Unit 1. Certain environmental Issues were Identified which required study or license conditions to resolve environmental concerns and to assure adequate protection of the environment.

2.1 Aquatic Issues No specific aquatic Issues were Identified by the NRC staff Inthe FES-OL. Effluent limitations and monitoring requirements are contained in the effective NPDES or LPDES permit Issued by the federal or state permitting authority. The NRC will rely on these agencies for regulation of these matters as they involve water quality and aquatic blota.

2.2 Terrestrial Issues Detection of possible changes In or damage to local flora caused by drift deposition due to the operation of the River Bend Station Cooling Towers. (FES-OL Section 5.14.1) 2.3 Noise Issues Adverse community reaction is expected from noise of operation of the plant (FES-OL, Section 5.12). A monitoring program to Identify the extent of Impacts and the mitigative actions necessary, If any, Is specified in Section 4.2. (FES-OL Section 5.14) 2-1 Amendment No. 138

3.0 Consistency Requirements 3.1 Plant Design and Operation The licensee may make changes in station design or operation or perform tests or experiments affecting the environment provided such activities do not Involve an unreviewed environmental question and do not Involve a change in the EPP*. Changes in station design or operation or performance of tests or experiments which do not affect the environment are not subject to the requirements of this EPP. Activities governed by Section 3.3 are not subject to the requirements of this Section.

Before engaging Inadditional construction or operational activities which may significantly affect the environment, the licensee shall prepare and record an environmental evaluation of such activity. Activities are excluded from this requirement if all measurable nonradiological environmental effects are confined to the on-site areas previously disturbed during site preparation and plant construction. When the evaluation Indicates that such activity involves an unreviewed environmental question, the licensee shall provide a written evaluation of such activity and obtain prior NRC approval. When such activity involves a change In the EPP, such activity and change to the EPP may be Implemented only in accordance with an appropriate license amendment as set forth InSection 5.3 of this EPP.

This provision does not relieve the licensee of the requirements of 10 CFR 50.59.

3-1 Amendment No. 138

A proposed change, test or experiment shall be deemed to involve an unreviewed environmental question if it concerns: (1)a matter which may result Ina significant increase In any adverse environmental impact previously evaluated in the FES-OL, environmental impact appraisals, or in any decisions of the Atomic Safety and Licensing Board; or (2) a significant change in effluents or power level; or (3)a matter, not previously reviewed and evaluated in the documents specified in (1)of this Subsection, which may have a significant adverse environmental impact.

The licensee shall maintain records of changes Infacility design or operation and of tests and experiments' carried out pursuant to this Subsection. These records shall include written evaluations which provide bases for the determination that the change, test, or experiment does not Involve an unreviewed environmental question or constitute a decrease in the effectiveness of this EPP to meet the objectives specified In Section 1.0.

K>

3.2 Reporting Related to the NPDES or LPDES Permit and State Certification The NRC shall be provided with a copy of the current NPDES or LPDES permit or State Clean Water Act, Section 401 certification within 30 days of approval. Changes to the NPDES or LPDES permit or state certification shall be reported to the NRC within 30 days of the date the change Isapproved.

3.3 Changes Required for Compliance with Other Environmental Regulations Changes in plant design or operation and performance of tests or experiments that are either regulated or mandated by other Federal, State, and local environmental regulations are not subject to the requirements of Section 3.1. However, if any environmental impacts of a change are not evaluated under other federal, state, or local environmental regulations, then K.. those impacts are subject to the requirements of Section 3.1.

3-2 Amendment No. 138

4.0 Environmental Conditions 4.1 Unusual or Important Environmental Events Any occurrence of an unusual or important event that indicates or could result In significant environmental Impact causally related to plant operation shall be recorded and reported to the NRC Operation Center within 24 hours1 days 0.143 weeks 0.0329 months followed by a written report per Subsection 5.4.2. Ifan event is reportable under 10 CFR 50.72, then a duplicate Immediate report under this Subsection Is not required. However, the follow-up written report per Subsection 5.4.2 is still required. The following are examples: excessive bird Impaction events, onsite plant or animal disease outbreaks, mortality or unusual occurrence of any species protected by the Endangered Species Act of 1973, fish kills, increase in nuisance organisms or conditions, and unanticipated or emergency discharge of waste water or chemical substances.

K> No routine monitoring programs are required to implement this condition.

4.2 Environmental Monitoring The terrestrial and noise monitoring programs Identified in Subsections 2.2 and 2.3 have been completed and no further monitoring under these programs is required.

4-1 Amendment No. 138

Z >Z 5.0 Administrative Procedures 5.1 Review and Audit The licensee shall provide for review and audit of compliance with the EPP. The audits shall be conducted Independently of the individual or groups responsible for performing the specific activity. A description of the organization structure utilized to achieve the independent review and audit function and results of the audit activities shall be maintained and made available for inspection.

5.2 Records Retention Records associated with this EPP shall be made and retained in a manner convenient for review and inspection. These records shall be made available to NRC on request.

K...I Records of modifications to station structures, systems and components determined to potentially affect the continued protection of the environment shall be retained until the date of termination of the license. All other records relating to this EPP shall be retained for five years or, where applicable, in accordance with the requirements of other agencies.

5.3 Changes in Environmental Protection Plan Requests for changes In the EPP shall Include an assessment of the environmental impact of the proposed change and a supporting justification. Implementation of such changes inthe EPP shall not commence prior to NRC approval of the proposed changes in the form of a license amendment incorporating the appropriate revision to the EPP.

5.4 Plant. Reporting Requirements 5.4.1 Deleted 5-1 Amendment No. 138

5.4.2 Nonroutine Reports A written report shall be submitted to the NRC within 30 days of occurrence of any event described In Section 4.1 of this plan. The report shall (a) describe, analyze, and evaluate the event, including extent and magnitude of the Impact, and plant operating characteristics, (b) describe the probable cause of the event, (c) Indicate the action taken to correct the reported event, (d) Indicate the corrective action taken to preclude repetition of the event and to prevent similar occurrences Involving similar components or systems, and (e) Indicate the agencies notified and their preliminary responses.

Events reportable under this subsection which also require reports to other Federal, State or local agencies shall be reported Inaccordance with those reporting requirements Inlieu of the requirements of this subsection. The NRC shall be provided with a copy of such report at the same time It is submitted to the other agency.

5-2 Amendment No. 138

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 APPENDIX C ANTITRUST CONDITIONS FACILITY OPERATING LICENSE NO. NPF-47 Entergy Louisiana, LLC, is subject to the following antitrust conditions:

( 1) Definitions (1)(a) "Bulk Power" means the electric power, and any attendant energy, supplied or made available at transmission or subtransmission voltage by an entity from its generating facilities.

( 1) (b) "Entity" means person, a private or public corporation, governmental agency, an association, a joint stock association, business trust, municipality, or rural electric cooperative owning, operating, or proposing to own or operate equipment facilities for the generation, transmission, or distribution of electricity primarily for sale or resale to the public. Provided, that, except for municipalities, governmental agencies, or rural electric cooperatives, "entity" is further restricted to those which are or will be public utilities under the laws of the State in which the entity transacts or will transact business or under the Federal Power Act, and are or will be providing electric service under a contract or rate schedule on file with and subject to the regulation of a State regulatory commission or the Federal Power Commission.

(1 )(c) "Cost" means all operating and maintenance expenses and ownership and capital costs properly allocable to the particular transaction.

"Cost" to be shared by participants under paragraph (9) shall include all costs of acquisition, construction, ownership, capital, operation, and maintenance reasonably allocable to the subject unit. Costs shall include no value for loss of revenues from sale of power at wholesale or retail by one party to a customer which another party might otherwise serve, except as otherwise authorized by any regulatory authority having jurisdiction. Costs shall include a reasonable return on Entergy Louisiana, LLC's investment.

(2) Entergy Louisiana, LLC shall interconnect with and coordinate reserves by means of the sale and purchase of emergency and/or scheduled maintenance bulk power with any entity(ies) in or within reasonable proximity to Entergy Louisiana, LLC's service area in Louisiana engaging in or proposing to engage in electric bulk power supply on terms that will provide for Entergy Louisiana, LLC's costs in connection therewith and allow the other entity(ies) full access to the benefits and obligations of reserve coordination.

Amendment No. 88, 4-aS, 192

(3) Such emergency service and/or scheduled maintenance service to be provided by each entity shall be furnished to the fullest extent available from the supplying entity and desired by the entity in need. Entergy Louisiana, LLC and each entity(ies) shall provide to the other such emergency service and/or scheduled maintenance service if and when available from its own generation and from generation of others to the extent it can do so without impairing service to its customers including other electric systems to whom it has firm commitments.

(4) Entergy Louisiana, LLC and the other entity(ies) which is (are) party(ies) to a reserve sharing arrangement shall from time to time jointly establish the minimum reserves to be installed and/or provided as necessary to maintain in total a reserve margin sufficient to provide adequate reliability of power supply to the interconnected systems of the parties, consistent with good utility industry practice in the region. If Entergy Louisiana, LLC plans its reserve margin on a pooled basis with other regional companies, the reserves jointly established hereunder shall be on the same basis. Unless otherwise agreed upon or established by such regional practice, minimum reserves shall be calculated as a percentage of estimated peak-load responsibility.

No party to the arrangement shall be required to maintain greater reserves than the percentage of its estimated peak-load responsibility which results from the aforesaid calculation; provided that if the reserve requirements of Entergy Louisiana, LLC are increased over the amount Entergy Louisiana, LLC would be required to maintain without such interconnection, then the other party(ies) shall be required to carry or provide for as its (their) reserves the full amount in kilowatts of such increase.

(5) The entities which are parties to such a reserve sharing agreement shall provide such amounts of ready reserve capacity as may be adequate to avoid the imposition of unreasonable demands on the others in meeting the normal contingencies of operating its system. However, in no circumstances shall the ready reserve requirement exceed the installed reserve requirement.

(6) Interconnections will not be limited to low voltages when higher voltages are available from Entergy Louisiana, LLC's installed facilities in the area where interconnection is desired, when the proposed arrangement is found to be technically and economically feasible. Control and telemetering facilities shall be provided as required for safe and prudent operation of the interconnected system.

(7) Interconnection and coordination agreements shall not embody any unlawful or unreasonably restrictive provisions pertaining to intersystem coordination. Good industry practice as developed in the area from time to time (if not unlawfully or unreasonably restrictive) will satisfy this provision.

Amendment No. 88, 458, 192

(8) Entergy Louisiana, LLC will sell (when available) bulk power at its costs to or purchase (when needed) bulk power from any other entity(ies) in or within reasonable proximity to Entergy Louisiana, LLC's service area in Louisiana engaging in or proposing to engage in generation of electric power at such entity(ies) cost when such transactions would serve to reduce the overall costs of new such bulk power supply, each for itself and for the other party(ies) to the transactions and would serve to coordinate the planning of new generation, transmission, and related facilities by both Entergy Louisiana, LLC and the other entity. This provision shall not be construed to require Entergy Louisiana, LLC to purchase or sell bulk power if it finds such purchase or sale infeasible or its costs in connection with such purchase or sale would exceed its benefits therefrom.

(9) Entergy Louisiana, LLC and any successor in title, shall offer an opportunity to participate in River Bend Station, Unit 1 for the term of the instant license, or any extensions or renewals thereof, or such term as Entergy Louisiana, LLC and the participant(s) may mutually agree upon, to any entity(ies) in or within reasonable proximity to Entergy Louisiana, LLC's service area in the State of Louisiana which has in writing requested participation therein prior to March 1, 1974, and which no later than March 31, 1975 has entered into an executory contract with respect to such participation, having taken all necessary action for it to lawfully do so prior to so doing, to a fair and reasonable extent and on reasonable terms and conditions and on a basis that fully compensate Entergy Louisiana, LLC for its costs incurred and to be incurred and that will not adversely affect the financing and constructing of this nuclear unit. Entergy Louisiana, LLC shall similarly offer an opportunity to participate in any additional nuclear generating unit(s) the power from which is intended for use in Entergy Louisiana, LLC's general system operations, which Entergy Louisiana, LLC may construct, own, and operate in Louisiana during the terms of the instant license(s), or any extension(s) or renewal(s), thereof.

Participation shall be either by ownership of or purchase of unit participation power from the respective nuclear units. Participation in any form shall be on an equitable basis whereby the participants, in proportion to their interests, share fully in all costs and risks of the respective nuclear units. In connection with such participation, Entergy Louisiana, LLC will offer transmission service as may be required for delivery of such power to such participants(s) on a basis that will fully compensate Entergy Louisiana, LLC for its costs.

(10) Entergy Louisiana, LLC shall facilitate the exchange of bulk power by transmission over its transmission facilities between two or more entities engaging in bulk power supply in its service area in Louisiana with which it is interconnected; and between any such entity(ies) and any entity(ies) engaging in bulk power supply outside Entergy Louisiana, LLC's service area in Louisiana between whose facilities Entergy Louisiana, LLC's transmission lines and other transmission lines would form Amendment No. 88, 4-§8, 192

a continuous electrical path; provided that (i) permission to utilize such other transmission lines has been obtained by the entities involved; (ii) Entergy Louisiana, LLC has appropriate agreements for transmission service with the entities interconnected with Entergy Louisiana, LLC at both the receiving and delivery points on Entergy Louisiana, LLC's system; and (iii) the arrangements reasonably can be accommodated from a functional and technical standpoint. Such transmission shall be on terms that fully compensate Entergy Louisiana, LLC for its cost. Any entity(ies) requesting such transmission arrangements shall give reasonable advance notice of its (their) schedule and requirements. (The foregoing applies to any entity(ies) engaging in bulk power supply to which Entergy Louisiana, LLC may be interconnected in the future as wellas those to which it is now interconnected.)

(11) Entergy Louisiana, LLC shall include in its planning and construction program sufficient transmission capacity as required for the transactions referred to in paragraph (10); provided, that any entity(ies) in its service area in Louisiana gives Entergy Louisiana, LLC sufficient advance notice as may be necessary to accommodate its (their) requirements from a functional and technical standpoint and that such entity(ies) fully compensate Entergy Louisiana, LLC for its cost.

Entergy Louisiana, LLC shall not be required to construct transmission facilities which will be of no demonstrable present or future benefit to Entergy Louisiana, LLC.

(12) Entergy Louisiana, LLC will sell power (when available) for resale to any entity(ies) in its service area in Louisiana now engaging in or proposing in good faith to engage in retail distribution of electric power, whenever power to meet the needs of such entity(ies) is not available form alternate sources at competitive costs.

(13) The foregoing conditions shall be in all respects implemented on reasonable terms and conditions in a manner consistent with the provisions of the Federal Power Act and other applicable Federal and State laws and regulatory orders, and shall be subject to force majeure, applicable curtailment programs, and engineering and technical feasibility for Entergy Louisiana, LLC's system. None of the foregoing conditions shall require Entergy Louisiana, LLC to sell power, perform any service, or engage in any course of action on a basis which would be unlawfully preferential or discriminatory under any applicable law or that would impair Entergy Louisiana, LLC's ability to render adequate and reliable service to its own customers. All rates, charges or practices in connection therewith are to be subject to the approval of regulatory agencies having jurisdiction over them.

Amendment No. 88, 408, 192

ML18284A370

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