Text

E-mail Regarding Entergy Handout for River Bend and NRC Public Conference Call on September 11, 2017, to Discuss Technical Specification Task Force Traveler 542
	ML17248A335
Person / Time
Site:	River Bend
Issue date:	08/24/2017
From:	Lisa Regner; Plant Licensing Branch IV
To:	Williamson D; Entergy Operations
	Regner, L M, 301-415-1906
References
	Download: ML17248A335 (60)
	v • d • e

From:

WILLIAMSON, DANNY H To:

Regner, Lisa

Subject:

[External_Sender] RE: draft TSTF-542 Date:

Thursday, August 24, 2017 10:28:27 AM Attachments:

River Bend application 1st draft.pdf TS markup package Aug 24.pdf

From: Regner, Lisa [1]

Sent: Thursday, August 24, 2017 9:26 AM To: WILLIAMSON, DANNY H

Subject:

RE: draft TSTF-542

EXTERNAL SENDER. DO NOT click links, or open attachments, if sender is unknown, or the message seems suspicious in any way.

DO NOT provide your user ID or password.

Yes.

Lisa Regner Sr. Project Manager NRR/DORL/LPL4 301-415-1906 O9D14

From: WILLIAMSON, DANNY H [2]

Sent: Thursday, August 24, 2017 10:25 AM To: Regner, Lisa <Lisa.Regner@nrc.gov>

Cc: Coates, Alyson <alacey@entergy.com>; SCHENK, TIMOTHY A <TSCHENK@entergy.com>

Subject:

[External_Sender] draft TSTF-542

Lisa

I have a draft application thats completed through the discussion on variances from the TSTF, as well as our markup pages. Would those be useful to you at this point?

Danny

TSTF542,Rev.2 Page1

[DATE]

10 CFR 50.90 ATTN: Document Control Desk U.S. Nuclear Regulatory Commission Washington, DC 20555-0001 River Bend Station DOCKET NO. 50-458

SUBJECT:

APPLICATION TO REVISE TECHNICAL SPECIFICATIONS TO ADOPT TSTF-542, "REACTOR PRESSURE VESSEL WATER INVENTORY CONTROL" Pursuant to 10 CFR 50.90, Entergy Operations, Inc. is submitting a request for an amendment to the Technical Specifications (TS) for River Bend Station, Unit 1.

The proposed change replaces existing Technical Specifications (TS) requirements related to "operations with a potential for draining the reactor vessel" (OPDRVs) with new requirements on Reactor Pressure Vessel Water Inventory Control (RPV WIC) to protect Safety Limit 2.1.1.3.

Safety Limit 2.1.1.3 requires reactor vessel water level to be greater than the top of active irradiated fuel.

provides a description and assessment of the proposed changes. Attachment 2 provides the existing TS pages marked to show the proposed changes. Attachment 3 provides revised (clean) TS pages. Attachment 4 provides existing TS Bases pages marked to show the proposed changes for information only.

Approval of the proposed amendment is requested by [date]. Once approved, the amendment shall be implemented within [ ] days.

In accordance with 10 CFR 50.91, a copy of this application, with attachments, is being provided to the designated Louisiana Official.

[In accordance with 10 CFR 50.30(b), a license amendment request must be executed in a signed original under oath or affirmation. This can be accomplished by attaching a notarized affidavit confirming the signature authority of the signatory, or by including the following statement in the cover letter: "I declare under penalty of perjury that the foregoing is true and correct.

Executed on (date)." The alternative statement is pursuant to 28 USC 1746. It does not require notarization.]

TSTF542,Rev.2 Page2

If you should have any questions regarding this submittal, please contact [NAME, TELEPHONE NUMBER].

Sincerely,

[Name, Title]

Attachments: 1. Description and Assessment

2. Proposed Technical Specification Changes (Mark-Up)

3. Revised Technical Specification Pages

4. Proposed Technical Specification Bases Changes (Mark-Up) cc: NRC Project Manager NRC Regional Office NRC Resident Inspector State Contact

TSTF542,Rev.2 Page3

ATTACHMENT 1 - DESCRIPTION AND ASSESSMENT

1.0 DESCRIPTION

The proposed change replaces existing Technical Specifications (TS) requirements related to "operations which have the potential for draining the reactor vessel" (OPDRVs) with new requirements on Reactor Pressure Vessel Water Inventory Control (RPV WIC) to protect Safety Limit 2.1.1.3. Safety Limit 2.1.1.3 requires reactor vessel water level to be greater than the top of active irradiated fuel.

2.0 ASSESSMENT

2.1 Applicability of Published Safety Evaluation Entergy Operations, Inc. has reviewed the safety evaluation provided to the Technical Specifications Task Force on [DATE], as well as the information provided in TSTF-542.

Entergy Operations, Inc. has concluded that the justifications presented in TSTF-542 and the safety evaluation prepared by the NRC staff are applicable to River Bend Station, Unit 1 and justify this amendment for the incorporation of the changes to the River Bend Station TS.

The following River Bend Station TS reference or are related to OPDRVs and are affected by the proposed change:

3.3.5.1, Emergency Core Cooling System (ECCS) Instrumentation 3.3.5.2, Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation [Note:

New TS]

3.3.5.3, Reactor Core Isolation Cooling (RCIC) System Instrumentation [Note: Changed from 3.3.5.2]

3.3.6.1, Primary Containment and Drywell Isolation Instrumentation 3.3.7.1, Control Room Fresh Air (CRFA) System Instrumentation 3.5.1, ECCS-Operating 3.5.2, ECCS - Shutdown 3.5.3, RCIC System 3.6.1.2, Primary Containment Air Locks 3.6.1.3, Primary Containment Isolation Valves (PCIVs) 3.6.1.10, Primary Containment-Shutdown 3.7.2, Control Room Fresh Air (CRFA) System 3.7.3, Control Room Air Conditioning (AC) System 3.8.2, AC Sources - Shutdown 3.8.5, DC Sources - Shutdown 3.8.8, Inverters - Shutdown 3.8.10, Distribution Systems - Shutdown 2.2 Variations ENTERGY OPERATIONS, INC. is proposing the following variations from the TS changes described in the TSTF-542 or the applicable parts of the NRC staffs safety evaluation:

The changes to TS 3.6.4.1: Secondary Containment - Operating; TS 3.6.4.2: Secondary Containment Isolation Valves (SCIVs), or as titled in the RBS TS: Secondary Containment Isolation Dampers (SCIDs) and Fuel Building Isolation Dampers; and TS 3.6.4.3 Standby Gas

TSTF542,Rev.2 Page4

Treatment (SGT) System as described in TSTF-542 are not applicable to the RBS TS. These TS will not be updated as a result of the adoption of TSTF-542.

The River Bend Station Technical Specifications do not contain a Surveillance Frequency Control Program. Therefore, the references to a Surveillance Frequency Control Program for Specification 3.5.2 are not included in the updated TS.

These variations do not affect the applicability of TSTF-542 or the NRC staff's safety evaluation to the proposed license amendment.

The River Bend Station TS utilize different numbering and titles than the Standard Technical Specifications on which TSTF-542 was based. The following table relates the administrative differences between the TS described in the TSTF-542 and the River Bend Station TS:

TSTF-542 TS Number TSTF-542 TS Title RBS TS Number RBS TS Title 3.3.5.2 ReactorPressureVessel (RPV)WaterInventory ControlInstrumentation New TS New TS 3.3.5.3 ReactorCoreIsolation Cooling(RCIC)System Instrumentation 3.3.5.2

[Changed to 3.3.5.3]

ReactorCoreIsolation Cooling(RCIC)System Instrumentation 3.3.6.1 PrimaryContainment Isolation Instrumentation Same PrimaryContainment andDrywellIsolation Instrumentation 3.3.6.2 SecondaryContainment Isolation Instrumentation Same SecondaryContainment andFuelBuilding Isolation Instrumentation 3.6.4.1

[Secondary]

Containment Same SecondaryContainment Operating 3.6.4.2 SecondaryContainment IsolationValves(SCIVs)

Same SecondaryContainment IsolationDampers (SCIDs)andFuel BuildingIsolation Dampers(FBIDs) 3.7.3 ControlRoomFreshAir (CRFA)System 3.7.2 Same 3.7.4

[ControlRoomAir Conditioning(AC)]

System 3.7.3 Same

TSTF542,Rev.2 Page5

These differences are administrative and do not affect the applicability of TSTF-542 to the River Bend Station TS.

The River Bend Station TS contain requirements that differ from the Standard Technical Specifications on which TSTF-542 was based, but are encompassed in the TSTF-542 justification:

Table 3.3.5.1-1 of the RBS TS currently contains requirements for Function 1.c, LPCS Pump Start-Time Delay Relay and for Function 2.d, LPCI Pump C Start-Time Delay Relay that are not included in the ISTS. In accordance with the justification included in TSTF-542, applicability to modes 4 and 5 are deleted because the instrumentation requirements during shutdown are being consolidated into the new TS 3.3.5.2.

Function 2.e, Reactor Vessel Pressure - Low (Injection Permissive), is listed as applicable in modes 4 and 5 while the corresponding ISTS Function, 2.d, Reactor Steam Dome Pressure -

Low (Injection Permissive) is not. In accordance with the justification included in TSTF-542, applicability to modes 4 and 5 are deleted because the instrumentation requirements during shutdown are being consolidated into the new TS 3.3.5.2.

Table 3.3.5.1-1 of the RBS TS contains administrative differences when compared to the ISTS. Functions 1.c and 2.d listed in the RBS TS Table 3.3.5.1-1 are not included in the ISTS. The inclusion of these functions in the RBS TS offset the numbering of the remaining functions from the ISTS.

Functions 1.e, Reactor Vessel Pressure-Low (Injection Permissive) and Function 2.e, Reactor Vessel Pressure-Low (Injection Permissive) of Table 3.3.5.1-1 of the RBS TS correspond with Function 1.d, Reactor Steam Dome Pressure - Low (Injection Permissive) and Function 2.d, Reactor Steam Dome Pressure - Low (Injection Permissive) of the ISTS. The functions of these instruments are identical to the corresponding instruments in the ISTS and differ in name only; therefore, this nomenclature is retained in TS Function 1.a and 2.a of the proposed TS Table 3.3.5.2-1.

RBS TS 3.3.6.1 is updated to remove note c from Table 3.3.6.1-1 in accordance with the TSTF-542 markup. All other changes made to the ISTS TS 3.3.6.1 by TSTF-542 are not applicable to the RBS TS because the RBS TS did not contain any other OPDRV related requirements or notes.

No changes were required to RBS TS 3.3.6.2, Secondary Containment and Fuel Building Isolation Instrumentation, because there are no existing OPDRV related requirements. This deviation is administrative because none of the items changed in the ISTS TS 3.3.6.2 exist in the current RBS TS 3.3.6.2. Secondary Containment Isolation Instrumentation is not required during OPDRV activities at RBS because [Secondary Containment] as described in the ISTS refers to the RBS Primary Containment (Refer to note 1 on page 6 of TSTF-542 revision 1).

RBS TS 3.6.1.10 required that Primary Containment be operable during OPDRVs rather than Secondary Containment.

Table 3.3.7-1 Function 1, Reactor Vessel Water Level - Low Low, Level 2, is not affected by the proposed RBS TS change while the note to the Applicable Modes of the corresponding function in the ISTS is changed in the ISTS TSTF-542 markup. The note stating that Function 1 was applicable during OPDRVs did not exist in the RBS TS and did not require

TSTF542,Rev.2 Page6

update. This is an administrative deviation from the ISTS changes and all other changes to Table 3.3.7-1 are consistent with the TSTF-542 markup.

The River Bend Station Technical Specifications contains a Note in TS 3.5.2 Surveillance Requirement 3.5.2.4 regarding realignment to the Low Pressure Coolant Injection mode.

However, this note is located in the LCO of ISTS 3.5.2. This note is updated to reflect the changes made by the TSTF-542 ISTS markup, but the location of the note is maintained in the Surveillance Requirement. This deviation is administrative and has no effect on the adoption of the TSTF-542.

The change made by TSTF-542 to Surveillance requirement 3.5.2.2 includes changing the word the to the word a referring to the required High Pressure Core Spray (HPCS) system. The RBS TS change administratively deviates from this change because RBS has only one HPCS system.

Required Actions C.3 and D.4 listed in the ISTS LCO 3.5.2 are not applicable to RBS because the Standby Gas Treatment Subsystem is external to the primary containment and not required for the operability of primary containment. Therefore, Required Action C.3 will not be incorporated into the RBS TS.

Required Action D.3 listed in the current RBS TS LCO 3.5.2 will be removed because the ISTS action D.2 to establish primary containment will require that the primary containment air locks be closed for completion. This action is no longer necessary.

RBS TS LCO 3.6.1.2 Primary Containment Air Locks, is currently applicable during OPDRV activities, this Applicability statement is removed along with Condition E Required Action 2 to suspend OPDRVs. The new drain time requirements of TS LCO 3.5.2 will preclude RPV Water Inventory Control activities with Drain Time <36 hours when at least one door in each Primary Containment Air Lock cannot be closed to restore Primary Containment. No additional Primary Containment Air Lock requirements are required.

RBS TS 3.6.4.1, Secondary Containment-Operating, is not affected by this TS change because there are no current OPDRV requirements for secondary containment. [Secondary Containment] in the ISTS refers to the RBS Primary Containment. RBS TS 3.6.1.10 Primary Containment-Shutdown is revised to remove OPDRV LCO Applicability requirement similar to the ISTS markup of TS 3.6.4.1.

RBS TS 3.6.4.2, Secondary Containment Isolation Dampers (SCIDs) and Fuel Building Isolation Dampers (FBIDs), like TS 3.6.4.1 above is not affected by this TS change because there are no current OPDRV requirements. The current RBS Secondary Containment Isolation TS do not contain OPDRV requirements because [Secondary Containment] as described in the ISTS refers to the RBS Primary Containment. The OPDRV requirements similar to those listed in the current ISTS for TS 3.6.4.2 are correlated with the current RBS TS requirements in TS 3.6.1.3, Primary Containment Isolation Valves (PCIVs). RBS TS 3.6.1.3 is revised to remove Required Action F.1 from Condition F and administratively updates Required Action F.2 to be listed as F.1.

RBS TS 3.6.4.3, Standby Gas Treatment (SGT) System, is not affected by this TS change because there are no current OPDRV requirements related to the SGT system. The SGT System is not required during RPV Water Inventory Control activities because the Standby

TSTF542,Rev.2 Page7

Gas Treatment Subsystem is external to the Primary Containment and is not required for Primary Containment Operability The ISTS 3.8.5 LCO Condition B is listed in the RBS TS 3.8.5 as LCO Condition A. The proposed changes made by TSTF-542 to ISTS 3.8.5 Condition B will be applied to RBS TS 3.8.5 Condition A. This deviation is strictly administrative.

3.0 REGULATORY ANALYSIS

3.1 No Significant Hazards Consideration Analysis Entergy Operations, Inc. requests adoption of TSTF-542 "Reactor Pressure Vessel Water Inventory Control," which is an approved change to the Standard Technical Specifications (ISTS), into the River Bend Station, Unit 1 Technical Specifications (TS). The proposed amendment replaces the existing requirements in the Technical Specifications (TS) related to "operations with a potential for draining the reactor vessel" (OPDRVs) with new requirements on Reactor Pressure Vessel Water Inventory Control (RPV WIC) to protect Safety Limit 2.1.1.3.

Safety Limit 2.1.1.3 requires reactor vessel water level to be greater than the top of active irradiated fuel.

Entergy Operations, Inc. has evaluated whether or not a significant hazards consideration is involved with the proposed amendment(s) by focusing on the three standards set forth in 10 CFR 50.92, "Issuance of amendment," as discussed below:

1.

Does the proposed amendment involve a significant increase in the probability or consequences of an accident previously evaluated?

Response: No The proposed change replaces existing TS requirements related to OPDRVs with new requirements on RPV WIC that will protect Safety Limit 2.1.1.3. Draining of RPV water inventory in Mode 4 (i.e., cold shutdown) and Mode 5 (i.e., refueling) is not an accident previously evaluated and, therefore, replacing the existing TS controls to prevent or mitigate such an event with a new set of controls has no effect on any accident previously evaluated. RPV water inventory control in Mode 4 or Mode 5 is not an initiator of any accident previously evaluated. The existing OPDRV controls or the proposed RPV WIC controls are not mitigating actions assumed in any accident previously evaluated.

The proposed change reduces the probability of an unexpected draining event (which is not a previously evaluated accident) by imposing new requirements on the limiting time in which an unexpected draining event could result in the reactor vessel water level dropping to the top of the active fuel (TAF). These controls require cognizance of the plant configuration and control of configurations with unacceptably short drain times. These requirements reduce the probability of an unexpected draining event. The current TS requirements are only mitigating actions and impose no requirements that reduce the probability of an unexpected draining event.

The proposed change reduces the consequences of an unexpected draining event (which is not a previously evaluated accident) by requiring an Emergency Core Cooling System (ECCS) subsystem to be operable at all times in Modes 4 and 5. The current TS requirements do not require any water injection systems, ECCS or otherwise, to be

TSTF542,Rev.2 Page8

Operable in certain conditions in Mode 5. The change in requirement from two ECCS subsystems to one ECCS subsystem in Modes 4 and 5 does not significantly affect the consequences of an unexpected draining event because the proposed Actions ensure equipment is available within the limiting drain time that is as capable of mitigating the event as the current requirements. The proposed controls provide escalating compensatory measures to be established as calculated drain times decrease, such as verification of a second method of water injection and additional confirmations that containment and/or filtration would be available if needed.

The proposed change reduces or eliminates some requirements that were determined to be unnecessary to manage the consequences of an unexpected draining event, such as automatic initiation of an ECCS subsystem and control room ventilation. These changes do not affect the consequences of any accident previously evaluated since a draining event in Modes 4 and 5 is not a previously evaluated accident and the requirements are not needed to adequately respond to a draining event.

Therefore, the proposed change does not involve a significant increase in the probability or consequences of an accident previously evaluated.

2. Does the proposed amendment create the possibility of a new or different kind of accident from any previously evaluated?

Response: No The proposed change replaces existing TS requirements related to OPDRVs with new requirements on RPV WIC that will protect Safety Limit 2.1.1.3. The proposed change will not alter the design function of the equipment involved. Under the proposed change, some systems that are currently required to be operable during OPDRVs would be required to be available within the limiting drain time or to be in service depending on the limiting drain time. Should those systems be unable to be placed into service, the consequences are no different than if those systems were unable to perform their function under the current TS requirements.

The event of concern under the current requirements and the proposed change is an unexpected draining event. The proposed change does not create new failure mechanisms, malfunctions, or accident initiators that would cause a draining event or a new or different kind of accident not previously evaluated or included in the design and licensing bases.

Therefore, the proposed change does not create the possibility of a new or different kind of accident from any previously evaluated.

3. Does the proposed amendment involve a significant reduction in a margin of safety?

Response: No The proposed change replaces existing TS requirements related to OPDRVs with new requirements on RPV WIC. The current requirements do not have a stated safety basis and no margin of safety is established in the licensing basis. The safety basis for the new requirements is to protect Safety Limit 2.1.1.3. New requirements are added to determine the limiting time in which the RPV water inventory could drain to the top of the fuel in the reactor vessel should an unexpected draining event occur. Plant configurations that could result in lowering the RPV water level to the TAF within one hour are now prohibited.

TSTF542,Rev.2 Page9

New escalating compensatory measures based on the limiting drain time replace the current controls. The proposed TS establish a safety margin by providing defense-in-depth to ensure that the Safety Limit is protected and to protect the public health and safety.

While some less restrictive requirements are proposed for plant configurations with long calculated drain times, the overall effect of the change is to improve plant safety and to add safety margin.

Therefore, the proposed change does not involve a significant reduction in a margin of safety.

Based on the above, Entergy Operations, Inc. concludes that the proposed change presents no significant hazards consideration under the standards set forth in 10 CFR 50.92(c), and, accordingly, a finding of "no significant hazards consideration" is justified.

4.0 ENVIRONMENTAL EVALUATION The proposed change would change a requirement with respect to installation or use of a facility component located within the restricted area, as defined in 10 CFR 20, or would change an inspection or surveillance requirement. However, the proposed change does not involve (i) a significant hazards consideration, (ii) a significant change in the types or significant increase in the amounts of any effluents that may be released offsite, or (iii) a significant increase in individual or cumulative occupational radiation exposure. Accordingly, the proposed change meets the eligibility criterion for categorical exclusion set forth in 10 CFR 51.22(c)(9).

Therefore, pursuant to 10 CFR 51.22(b), no environmental impact statement or environmental assessment need be prepared in connection with the proposed change.

TECHNICAL SPECIFICATIONS TABLE OF CONTENTS (continued)

RIVER BEND ii Revision No. 6-5 B 3.2 POWER DISTRIBUTION LIMITS B 3.2.1 AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR)......... B 3.2-1 B 3.2.2 MINIMUM CRITICAL POWER RATIO (MCPR)......................... B 3.2-5 B 3.2.3 LINEAR HEAT GENERATION RATE (LHGR).......................... B 3.2-9 B 3.2.4 FRACTION OF CORE BOILING BOUNDARY (FCBB).................... B 3.2-12 3.3 INSTRUMENTATION 3.3.1.1 Reactor Protection System (RPS) Instrumentation............. 3.3-1 3.3.1.2 Source Range Monitor (SRM) Instrumentation.................. 3.3-10 3.3.1.3 Period Based Detection System (PBDS)........................ 3.3-14a 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...................................... 3.3-23 3.3.4.1 End of Cycle Recirculation Pump Trip (EOC-RPT)

Instrumentation........................................ 3.3-25 3.3.4.2 Anticipated Transient Without Scram Recirculation Pump Trip (ATWS-RPT) Instrumentation................... 3.3-29 3.3.5.1 Emergency Core Cooling System (ECCS) Instrumentation........ 3.3-32 3.3.5.2 Reactor Core Isolation Cooling (RCIC) System Instrumentation........................................ 3.3-44 3.3.6.1 Primary Containment and Drywell Isolation Instrumentation........................................ 3.3-48 3.3.6.2 Secondary Containment and Fuel Building Isolation Instrumentation......................................... 3.3-58 3.3.6.3 Containment Unit Cooler System Instrumentation.............. 3.3-62 3.3.6.4 Relief and Low-Low Set (LLS) 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 B 3.3 INSTRUMENTATION B 3.3.1.1 Reactor Protection System (RPS) Instrumentation................. B 3.3-1 B 3.3.1.2 Source Range Monitor (SRM) Instrumentation...................... B 3.3-32 B 3.3.1.3 Period Based Detection System (PBDS)............................ B 3.3-39a B 3.3.2.1 Control Rod Block Instrumentation............................... B 3.3-40 B 3.3.3.1 Post Accident Monitoring (PAM) Instrumentation.................. B 3.3-49 B 3.3.3.2 Remote Shutdown System.......................................... B 3.3-60 B 3.3.4.1 End of Cycle Recirculation Pump Trip (EOC-RPT)

Instrumentation........................................ B 3.3-65 B 3.3.4.2 Anticipated Transient Without Scram Recirculation Pump Trip (ATWS-RPT) Instrumentation................... B 3.3-76 B 3.3.5.1 Emergency Core Cooling System (ECCS) Instrumentation............ B 3.3-85 B 3.3.5.2 Reactor Core Isolation Cooling (RCIC) System Instrumentation........................................ B 3.3-122 3.3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation....................................................................3.3-43a 3

B 3.3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Instrumentation............................................................................. B 3.3 121a 3

TECHNICAL SPECIFICATIONS TABLE OF CONTENTS RIVER BEND iv Revision No. 167 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.1 ECCS - Operating................................................................................ 3.5-1 3.5.2 ECCS - Shutdown RPV Water Inventory Control.................................. 3.5-6 3.5.3 RCIC System....................................................................................... 3.5-10 B 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM B 3.5.1 ECCS - Operating................................................................................ B 3.5-1 B 3.5.2 ECCS - Shutdown RPV Water Inventory Control............................... B 3.5-15 B 3.5.3 RCIC System....................................................................................... B 3.5-20 3.6 CONTAINMENT SYSTEMS 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 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 DELETED............................................................................................3.6-39 3.6.3.2 Primary Containment and Drywell Hydrogen Igniters.......................... 3.6-41 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) and Fuel Building Isolation Dampers (FBIDs)............................................ 3.6-48 3.6.4.3 Standby Gas Treatment (SGT) System............................................... 3.6-51 3.6.4.4 DELETED............................................................................................ 3.6-53 3.6.4.5 Fuel Building........................................................................................ 3.6-55 3.6.4.6 DELETED............................................................................................ 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................................................................................... 3.6-63 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 B 3.6 CONTAINMENT SYSTEMS B 3.6.1.1 Primary Containment - Operating........................................................ B 3.6-1 B 3.6.1.2 Primary Containment Air Locks........................................................... B 3.6-5 B 3.6.1.3 Primary Containment Isolation Valves (PCIVs)................................... B 3.6-15 B 3.6.1.4 Primary Containment Pressure........................................................... B 3.6-30 (continued)

, REACTOR PRESSURE VESSEL (RPV) WATER INVENTORY CONTROL,

Definitions 1.1 1.1 Definitions (continued)

RIVER BEND 1.0-2 Amendment No. 81, 132 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 I-131 DOSE EQUIVALENT I-131 shall be that concentration of I-131 (microcuries/gram) that alone would produce the same thyroid dose as the quantity and isotopic mixture of I-131, I-132, I-133, I-134, and I-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)

Insert "A"

(InsertA)

TS1.1 DRAIN TIME The DRAIN TIME is the time it would take for the water inventory in and above the Reactor Pressure Vessel (RPV) to drain to the top of the active fuel (TAF) seated in the RPV assuming:

a) The water inventory above the TAF is divided by the limiting drain rate; b) The limiting drain rate is the larger of the drain rate through a single penetration flow path with the highest flow rate, or the sum of the drain rates through multiple penetration flow paths susceptible to a common mode failure (e.g., seismic event, loss of normal power, single human error), for all penetration flow paths below the TAF except:

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

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

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

c) The penetration flow paths required to be evaluated per paragraph b) are assumed to open instantaneously and are not subsequently isolated, and no water is assumed to be subsequently added to the RPV water inventory; d) No additional draining events occur; and e) Realistic cross-sectional areas and drain rates are used.

A bounding DRAIN TIME may be used in lieu of a calculated value.

ECCS Instrumentation 3.3.5.1 RIVER BEND 3.3-32 Amendment No. 81 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 inoperable.

A.1 Enter the Condition referenced in Table 3.3.5.1-1 for the channel.

Immediately B.

As required by Required Action A.1 and referenced in Table 3.3.5.1-1.

B.1

NOTES----------

1.

Only applicable in MODES 1, 2, and 3.

2.

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

Declare supported feature(s) inoperable when its redundant feature ECCS initiation capability is inoperable.

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

ECCS Instrumentation 3.3.5.1 RIVER BEND 3.3-33 Amendment No. 81 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 Core Spray (HPCS)

System inoperable.

AND B.3 Place channel in trip.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from discovery of loss of HPCS initiation capability 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months C.

As required by Required Action A.1 and referenced in Table 3.3.5.1-1.

C.1

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

1.

Only applicable in MODES 1, 2, and 3.

2.

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

Declare supported feature(s) inoperable when its redundant feature ECCS initiation capability is inoperable.

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

ECCS Instrumentation 3.3.5.1 RIVER BEND 3.3-35 Amendment No. 81 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E.

As required by Required Action A.1 and referenced in Table 3.3.5.1-1.

E.1

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

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

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

Declare supported feature(s) inoperable when its redundant feature ECCS initiation capability is inoperable.

AND E.2 Restore channel to OPERABLE status.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from discovery of loss of initiation capability for feature(s) in both divisions 7 days F.

As required by Required Action A.1 and referenced in Table 3.3.5.1-1.

F.1 Declare Automatic Depressurization System (ADS) valves inoperable.

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

ECCS Instrumentation 3.3.5.1 RIVER BEND 3.3-39 Amendment No. 81 Table 3.3.5.1-1 (page 1 of 5)

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

1.

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

a.

Reactor Vessel Water Level

Low Low Low, Level 1 1,2,3, 4(a),5(a) 2(b)

B SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6 t -147 inches

b.

Drywell PressureHigh 1,2,3 2(b)

B SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6 d 1.88 psid

c.

LPCS Pump StartTime Delay Relay 1,2,3, 4(a),5(a) 1 C

SR 3.3.5.1.2 SR 3.3.5.1.4 SR 3.3.5.1.6 t 1.8 seconds and d 2.2 seconds

d.

LPCI Pump A StartTime Delay Relay 1,2,3, 4(a),5(a) 1 C

SR 3.3.5.1.2 SR 3.3.5.1.4 SR 3.3.5.1.6 t 6.3 seconds and d 7.7 seconds

e.

Reactor Vessel PressureLow (Injection Permissive) 1,2,3 4

C SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6 t 472 psig and d 502 psig 4(a),5(a) 4 B

SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6 t 472 psig and d 502 psig

f.

LPCS Pump Discharge FlowLow (Bypass) 1,2,3, 4(a),5(a) 1 E

SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6 t 750 gpm

g.

LPCI Pump A Discharge FlowLow (Bypass) 1,2,3, 4(a),5(a) 1 E

SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6 t 900 gpm

h.

Manual Initiation 1,2,3, 4(a),5(a) 1 per system C

SR 3.3.5.1.6 NA (continued)

(a)

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

(b)

Also required to initiate the associated diesel generator.

a a

ECCS Instrumentation 3.3.5.1 RIVER BEND 3.3-40 Amendment No. 81 Table 3.3.5.1-1 (page 2 of 5)

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

2.

LPCI B and LPCI C Subsystems

a.

Reactor Vessel Water LevelLow Low Low, Level 1 1,2,3, 4(a),5(a) 2(b)

B SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6 t -147 Inches

b.

Drywell PressureHigh 1,2,3 2(b)

B SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6 d 1.88 psid

c.

LPCI Pump B StartTime Delay Relay 1,2,3, 4(a),5(a) 1 C

SR 3.3.5.1.2 SR 3.3.5.1.4 SR 3.3.5.1.6 t 6.3 seconds and d 7.7 seconds

d.

LPCI Pump C StartTime Delay Relay 1,2,3, 4(a),5(a) 1 C

SR 3.3.5.1.2 SR 3.3.5.1.4 SR 3.3.5.1.6 t 1.8 seconds and d 2.2 seconds

e.

Reactor Vessel PressureLow (Injection Permissive) 1,2,3 4

C SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6 t 472 psig and d 502 psig 4(a),5(a) 4 B

SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6 t 472 psig and d 502 psig

f.

LPCI Pump B and LPCI Pump C Discharge FlowLow (Bypass) 1,2,3, 4(a),5(a) 1 per pump E

SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6 t 900 gpm

g.

Manual Initiation 1,2,3, 4(a),5(a) 1 C

SR 3.3.5.1.6 NA (continued)

(a)

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

(b)

Also required to initiate the associated diesel generator.

a a

ECCS Instrumentation 3.3.5.1 RIVER BEND 3.3-41 Amendment No. 81 Table 3.3.5.1-1 (page 3 of 5)

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

3.

High Pressure Core Spray (HPCS) System

a.

Reactor Vessel Water LevelLow Low, Level 2 1,2,3, 4(a),5(a) 4(b)

B SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6 t -47 inches

b.

Drywell Pressure High 1,2,3 4(b)

B SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6 d 1.88 psid

c.

Reactor Vessel Water LevelHigh, Level 8 1,2,3, 4(a),5(a) 2 C

SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6 d 55 inches

d.

Condensate Storage Tank LevelLow 1,2,3, 4(c),5(c) 2 D

SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6 t -4.5 inches

e.

Suppression Pool Water LevelHigh 1,2,3 2

D SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6 d 8 inches

f.

HPCS Pump Discharge PressureHigh (Bypass) 1,2,3, 4(a),5(a) 1 E

SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6 t 275 psig

g.

HPCS System Flow RateLow (Bypass) 1,2,3, 4(a),5(a) 1 E

SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6 t 710 gpm

h.

Manual Initiation 1,2,3, 4(a),5(a) 1 C

SR 3.3.5.1.6 NA (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, "ECCSShutdown," and aligned to the condensate storage tank while tank water level is not within the limit of SR 3.5.2.2.

a a

ECCS Instrumentation 3.3.5.1 RIVER BEND 3.3-42 Amendment No. 81 Table 3.3.5.1-1 (page 4 of 5)

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

4.

Automatic Depressurization System (ADS) Trip System A

a.

Reactor Vessel Water LevelLow Low Low, Level 1 1,2(d),3(d) 2 F

SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6 t -147 inches

b.

Drywell PressureHigh 1,2(d),3(d) 2 F

SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6 d 1.88 psid

c.

ADS Initiation Timer 1,2(d),3(d) 1 G

SR 3.3.5.1.2 SR 3.3.5.1.4 SR 3.3.5.1.6 d 117 seconds

d.

Reactor Vessel Water LevelLow, Level 3 (Confirmatory) 1,2(d),3(d) 1 F

SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6 t 8.7 inches

e.

LPCS Pump Discharge Pressure High 1,2(d),3(d) 2 G

SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6 t 130 psig

f.

LPCI Pump A Discharge PressureHigh 1,2(d),3(d) 2 G

SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6 t 120 psig

g.

ADS Bypass Timer (High Drywell Pressure) 1,2(d),3(d) 2 G

SR 3.3.5.1.2 SR 3.3.5.1.4 SR 3.3.5.1.6 d 5.5 minutes

h.

Manual Initiation 1,2(d),3(d) 2 per system G

SR 3.3.5.1.6 NA (continued)

(d)

With reactor steam dome pressure > 100 psig.

(Re-number all Notes on this page from "d" to "b".

ECCS Instrumentation 3.3.5.1 RIVER BEND 3.3-43 Amendment No. 81 Table 3.3.5.1-1 (page 5 of 5)

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

5.

ADS Trip System B

a.

Reactor Vessel Water LevelLow Low Low, Level 1 1,2(d),3(d) 2 F

SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6 t -147 Inches

b.

Drywell PressureHigh 1,2(d),3(d) 2 F

SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6 d 1.88 psid

c.

ADS Initiation Timer 1,2(d),3(d) 1 G

SR 3.3.5.1.2 SR 3.3.5.1.4 SR 3.3.5.1.6 d 117 seconds

d.

Reactor Vessel Water Level-Low, Level 3 (Confirmatory) 1,2(d),3(d) 1 F

SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6 t 8.7 Inches

e.

LPCI Pumps B & C Discharge PressureHigh 1,2(d),3(d) 2 per pump G

SR 3.3.5.1.1 SR 3.3.5.1.2 SR 3.3.5.1.3 SR 3.3.5.1.5 SR 3.3.5.1.6 t 120 psig

f.

ADS Bypass Timer (High Drywell Pressure) 1,2(d),3(d) 2 G

SR 3.3.5.1.2 SR 3.3.5.1.4 SR 3.3.5.1.6 d 5.5 minutes

g.

Manual Initiation 1,2(d),3(d) 2 per system G

SR 3.3.5.1.6 NA (continued)

(d)

With reactor steam dome pressure > 100 psig.

(Re-number all Notes on this page from "d" to "b".

RPV Water Inventory Control Instrumentation 3.3.5.2 RIVER BEND 3.3-43a Amendment No. xxx 3.3 INSTRUMENTATION 3.3.5.2 Reactor Pressure Vessel (RPV) Water Inventory Control Instrumentation LCO 3.3.5.2 The RPV Water Inventory Control instrumentation for each Function in Table 3.3.5.2-1 shall be OPERABLE.

APPLICABILITY:

According to Table 3.3.5.2-1.

ACTIONS

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

Separate Condition entry is allowed for each channel.

CONDITION REQUIRED ACTION COMPLETION TIME A.

One or more channels inoperable.

A.1 Enter the Condition referenced in Table 3.3.5.2-1 for the channel.

Immediately B.

As required by Required Action A.1 and referenced in Table 3.3.5.2-1.

B.1 Declare associated flow path(s) incapable of automatic isolation.

AND B.2 Calculate DRAIN TIME.

Immediately Immediately C.

As required by Required Action A.1 and referenced in Table 3.3.5.2-1.

C.1 Place channel in trip.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months (continued)

RPV Water Inventory Control Instrumentation 3.3.5.2 RIVER BEND 3.3-43b Amendment No. xxx ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D.

As required by Required Action A.1 and referenced in Table 3.3.5.2-1.

D.1 Declare HPCS system inoperable OR D.2 Align the HPCS pump suction to the suppression pool.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months 1 hour E.

As required by Required Action A.1 and referenced in Table 3.3.5.2-1.

E.1 Declare HPCS system inoperable AND E.2 Restore channel to OPERABLE status.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months 24 hours F.

As required by Required Action A.1 and referenced in Table 3.3.5.2-1.

F.1 Restore channel to OPERABLE status.

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months G. Required Action and associated Completion Time of Condition C, D, E, or F not met.

G.1 Declare associated ECCS injection/spray subsystem inoperable.

Immediately

RPV Water Inventory Control Instrumentation 3.3.5.2 RIVER BEND 3.3-43c Amendment No.xxx SURVEILLANCE REQUIREMENTS

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

Refer to Table 3.3.5.2-1 to determine which SRs apply for each ECCS function.

SURVEILLANCE FREQUENCY SR 3.3.5.2.1 Perform CHANNEL CHECK.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.3.5.2.2 Perform CHANNEL FUNCTIONAL TEST.

92 days SR 3.3.5.2.3 Perform LOGIC SYSTEM FUNCTIONAL TEST.

24 months

RPV Water Inventory Control Instrumentation 3.3.5.2 RIVER BEND 3.3-43d Amendment No.xxx Table 3.3.5.2-1 (page 1 of 2)

RPV Water Inventory Control Instrumentation

FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS PER FUNCTION CONDITIONS REFERENCE FROM REQUIRED ACTION A.1 SURVEILLANCE REQUIREMENTS ALLOWABLE VALUE

1.

Low Pressure Coolant Injection A (LPCI) and Low Pressure Core Spray (LPCS) Subsytems

a.

Reactor Vessel Pressure - Low (Injection Permissive) 4, 5 4(a)

C SR 3.3.5.2.1 SR 3.3.5.2.2 472 psig 502 psig

b.

LPCS Pump Discharge Flow -

Low (Bypass) 4, 5 1(a)

F SR 3.3.5.2.1 SR 3.3.5.2.2 750 gpm

c.

LPCI Pump A Discharge Flow -

Low (Bypass) 4, 5 1(a)

F SR 3.3.5.2.1 SR 3.3.5.2.2 900 gpm

d.

Manual Initiation 4, 5 1 per system (a)

F SR 3.3.5.2.3 NA

2.

LPCI B and LPCI C Subsytems

a.

Reactor Vessel Pressure - Low (Injection Permissive) 4, 5 4(a)

C SR 3.3.5.2.1 SR 3.3.5.2.2 472 psig 502 psig

b.

LPCI Pump B and LPCI Pump C Discharge Flow -

Low (Bypass) 4, 5 1 per pump (a)

F SR 3.3.5.2.1 SR 3.3.5.2.2 900 gpm

c.

Manual Initiation 4, 5 1(a)

F SR 3.3.5.2.3 NA

3.

High Pressure Core Spray (HPCS) System

a.

Reactor Vessel Water Level - High (Level 8) 4, 5 2(a)

E SR 3.3.5.2.1 SR 3.3.5.2.2 55 inches

b.

Condensate Storage Tank Level - Low 4(b), 5(b) 2(a)

D SR 3.3.5.2.1 SR 3.3.5.2.2 4.5 inches

c.

HPCS Pump Discharge Pressure

- High (Bypass) 4, 5 1(a)

F SR 3.3.5.2.1 SR 3.3.5.2.2 275 psig

d.

HPCS System Flow Rate - Low (Bypass) 4, 5 1(a)

F SR 3.3.5.2.1 SR 3.3.5.2.2 710 gpm

e.

Manual Initiation 4, 5 1(a)

F SR 3.3.5.2.3 NA (a)

Associated with an ECCS subsystem required to be OPERABLE by LCO 3.5.2, Reactor Pressure Vessel Water Inventory Control.

(b)

When HPCS is OPERABLE for compliance with LCO 3.5.2, RPV Water Inventory Control and aligned to the condensate storage tank.

RPV Water Inventory Control Instrumentation 3.3.5.2 RIVER BEND 3.3-43e Amendment No.xxx Table 3.3.5.2-1 (page 2 of 2)

RPV Water Inventory Control Instrumentation

FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS PER FUNCTION CONDITIONS REFERENCE FROM REQUIRED ACTION A.1 SURVEILLANCE REQUIREMENTS ALLOWABLE VALUE

4.

RHR System Isolation

a.

Reactor Vessel Water Level - Low (Level 3)

(c) 2 B

SR 3.3.5.2.1 SR 3.3.5.2.2 8.7 inches

5.

Reactor Water Cleanup (RWCU) System Isolation

a.

Reactor Water Level

- Low, Low (Level

2)

(c) 2 B

SR 3.3.5.2.1 SR 3.3.5.2.2 4.7 inches (c) When automatic isolation of the associated penetration flow path(s) is credited in calculating DRAIN TIME.

RCIC System Instrumentation 3.3.5.2 RIVER BEND 3.3-44 Amendment No. 81 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 inoperable.

A.1 Enter the Condition referenced in Table 3.3.5.2-1 for the channel.

Immediately B.

As required by Required Action A.1 and referenced in Table 3.3.5.2-1.

B.1 Declare RCIC System inoperable.

AND B.2 Place channel in trip.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from discovery of loss of RCIC initiation capability 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months C.

As required by Required Action A.1 and referenced in Table 3.3.5.2-1.

C.1 Restore channel to OPERABLE status.

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

(replace all deleted characters on this page with "3")

RCIC System Instrumentation 3.3.5.2 RIVER BEND 3.3-45 Amendment No. 81 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D.

As required by Required Action A.1 and referenced in Table 3.3.5.2-1.

D.1

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

Only applicable if RCIC pump suction is not aligned to the suppression pool.

Declare RCIC System inoperable.

AND D.2.1 Place channel in trip.

OR D.2.2 Align RCIC pump suction to the suppression pool.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from discovery of loss of RCIC initiation capability 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months 24 hours E.

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

E.1 Declare RCIC System inoperable.

Immediately (replace all deleted characters on this page with "3")

RCIC System Instrumentation 3.3.5.2 RIVER BEND 3.3-46 Amendment No. 81, 168 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 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Functions 2 and 5; and (b) for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Functions 1, 3, and 4 provided the associated Function maintains RCIC initiation capability.

SURVEILLANCE FREQUENCY SR 3.3.5.2.1 Perform CHANNEL CHECK.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 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 (replace all deleted characters on this page with "3")

RCIC System Instrumentation 3.3.5.2 RIVER BEND 3.3-47 Amendment No. 81 Table 3.3.5.2-1 (page 1 of 1)

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

1.

Reactor Vessel Water LevelLow Low, Level 2 4

B SR 3.3.5.2.1 SR 3.3.5.2.2 SR 3.3.5.2.3 SR 3.3.5.2.4 SR 3.3.5.2.5 t -47 inches

2.

Reactor Vessel Water LevelHigh, Level 8 2

C SR 3.3.5.2.1 SR 3.3.5.2.2 SR 3.3.5.2.3 SR 3.3.5.2.4 SR 3.3.5.2.5 d 52 inches

3.

Condensate Storage Tank LevelLow 2

D SR 3.3.5.2.1 SR 3.3.5.2.2 SR 3.3.5.2.3 SR 3.3.5.2.4 SR 3.3.5.2.5 t -4.5 inches

4.

Suppression Pool Water LevelHigh 2

D SR 3.3.5.2.1 SR 3.3.5.2.2 SR 3.3.5.2.3 SR 3.3.5.2.4 SR 3.3.5.2.5 d 8 inches

5.

Manual Initiation 1

C SR 3.3.5.2.5 NA (replace all deleted characters on this page with "3")

Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 RIVER BEND 3.3-57 Amendment No. 81 Table 3.3.6.1-1 (page 5 of 5)

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

5.

RHR System Isolation

a.

RHR Equipment Room Ambient TemperatureHigh 1,2,3 2

F SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 d 121.1qF

b.

Reactor Vessel Water LevelLow, Level 3 1,2,3(c) 2 F

SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6 t 8.7 Inches 3(d),4,5 2(e)

J SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6 t 8.7 inches

c.

Reactor Vessel Water Level

Low Low Low, Level 1 1,2,3 2

F SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6 t -147 Inches

d.

Reactor Steam Dome Pressure

High 1,2,3 2

F SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6 d 150 psig

e.

Drywell Pressure High 1,2,3 2

F SR 3.3.6.1.1 SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.5 SR 3.3.6.1.6 d 1.88 psid

f.

Manual Initiation 1,2,3 2

G SR 3.3.6.1.6 NA (c)

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.

CRFA System Instrumentation 3.3.7.1 RIVER BEND 3.3-71 Amendment No. 81 95 119, 132 Table 3.3.7.1-1 (page 1 of 1)

Control Room Fresh Air System Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS PER TRIP SYSTEM CONDITIONS REFERENCED FROM REQUIRED ACTION A.1 SURVEILLANCE REQUIREMENTS ALLOWABLE VALUE

1.

Reactor Vessel Water Level -

Low Low, Level 2 1,2,3 2

B SR 3.3.7.1.1 SR 3.3.7.1.2 SR 3.3.7.1.3 SR 3.3.7.1.4 SR 3.3.7.1.5

-47 inches

2.

Drywell Pressure - High 1,2,3 2

C SR 3.3.7.1.1 SR 3.3.7.1.2 SR 3.3.7.1.3 SR 3.3.7.1.4 SR 3.3.7.1.5 1.88 psid

3.

Control Room Local Intake Ventilation Radiation Monitors 1,2,3 (a),(b) 1 D

SR 3.3.7.1.1 SR 3.3.7.1.2 SR 3.3.7.1.4 SR 3.3.7.1.5 0.97 x 10-5

µCi/cc (a)

During operations with a potential for draining the reactor vessel.

(ba)

During movement of recently irradiated fuel assemblies in the primary containment or fuel building.

ECCS Operating 3.5.1 RIVER BEND 3.5-1 Amendment No. 81, 156 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 100 psig.

ACTIONS

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

LCO 3.0.4.b is not applicable to HPCS.

CONDITION REQUIRED ACTION COMPLETION TIME A.

One low pressure ECCS injection/spray subsystem inoperable.

A.1 Restore low pressure ECCS injection/spray subsystem to OPERABLE status.

7 days B.

High Pressure Core Spray (HPCS) System inoperable.

B.1 Verify by administrative means RCIC System is OPERABLE when RCIC is required to be OPERABLE.

AND B.2 Restore HPCS System to OPERABLE status.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months 14 days (continued)

, RPV WATER INVENTORY CONTROL,

ECCS Shutdown 3.5.2 RIVER BEND 3.5-6 Amendment No. 81 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (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 23 ft over the top of the reactor pressure vessel flange.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

One required ECCS injection/spray subsystem inoperable.

A.1 Restore required ECCS injection/spray subsystem to OPERABLE status.

4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months B.

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

B.1 Initiate action to suspend operations with a potential for draining the reactor vessel (OPDRVs).

Immediately C.

Two required ECCS injection/spray subsystems inoperable.

C.1 Initiate action to suspend OPDRVs.

AND C.2 Restore one ECCS injection/spray subsystem to OPERABLE status.

Immediately 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months (continued)

, RPV WATER INVENTORY CONTROL, RPV Water Inventory Control Initiate action to establish a method of water injection capable of operating without offsite electrical power.

R MODES 4 and 5 Reactor Pressure Vessel (RPV) Water Inventory Control DRAIN TIME of RPV water inventory to the top of active fuel (TAF) shall be 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

AND (Insert "B" here)

One (Insert "G")

(InsertG)

TS3.5.2Note

NOTE Alowpressurecoolantinjection(LPCI)subsystemmaybeconsideredOPERABLEduringalignmentand operationfordecayheatremoval,ifcapableofbeingmanuallyrealignedandnototherwiseinoperable.

(InsertB)

TS3.5.2

C.

DRAINTIME<36 hoursand>8hours

C.1 Verifyprimarycontainmentboundaryis capableofbeingestablishedinlessthanthe DRAINTIME

4hours

AND

C.2 Verifyeachprimarycontainmentpenetration flowpathiscapableofbeingisolatedwithin theDRAINTIME.

4hours D. DRAINTIME<8 hours.

D.1 NOTE RequiredECCSinjection/spraysubsystemor additionalmethodofwaterinjectionshallbe capableofoperatingwithoutoffsiteelectrical power.

Initiateactiontoestablishanadditional methodofwaterinjectionwithwatersources capableofmaintainingRPVwaterlevel>TAF for36hours.

Immediately

AND

D.2 Initiateactiontoestablishprimarycontainment boundary.

Immediately

AND

D.3 Initiateactiontoisolateeachprimary containmentpenetrationflowpathorverifyit canbemanuallyisolatedfromthecontrol room.

Immediately E.

RequiredActionand associated CompletionTimeof ConditionCorDnot met.

OR

DRAINTIME<1 hour.

E.1 InitiateactiontorestoreDRAINTIMEto36 hours.

Immediately

ECCS Shutdown 3.5.2 RIVER BEND 3.5-7 Amendment No. 81 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D.

Required Action C.2 and associated Completion Time not met.

D.1 Initiate action to restore primary containment to OPERABLE status.

AND D.2 Initiate action to isolate required primary containment penetration flow paths.

AND D.3

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

Entry and exit is permissible under administrative control.

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

Immediately Immediately Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify, for each required low pressure ECCS injection/spray subsystem, the suppression pool water level is 13 ft 3 inches.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued) a 2

RPV Water Inventory Control (Insert "C" here)

(InsertC)

TS3.5.2

SR3.5.2.1 VerifyDRAINTIMEis36hours.

12hours

ECCS Shutdown 3.5.2 RIVER BEND 3.5-8 Amendment No. 81, 188 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.2.2 Verify, for the required High Pressure Core Spray (HPCS) System, the:

a.

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

Condensate storage tank water level is 11 ft 1 inch.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.5.2.3 Verify, for each required ECCS injection/spray subsystem, locations susceptible to gas accumulation are sufficiently filled with water.

31 days SR 3.5.2.4

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

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 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.

31 days (continued) 3 4

5 the

, for the

, each RPV Water Inventory Control

ECCS Shutdown 3.5.2 RIVER BEND 3.5-9 Amendment No. 81, 168 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.2.5 Verify each required ECCS pump develops the specified flow rate with the specified pump differential pressure.

PUMP DIFFERENTIAL SYSTEM FLOW RATE PRESSURE LPCS 5010 gpm 282 psid LPCI 5050 gpm 102 psid HPCS 5010 gpm 415 psid In accordance with the Inservice Testing Program SR 3.5.2.6

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

Vessel injection/spray may be excluded.

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

24 months RPV Water Inventory Control 6

8 Operate the required ECCS injection/

spray subsystem through the recirculation line for 10 minutes.

92 days (Insert "D")

Verify the required ECCS injection / spray subsystem actuates on a manual initiation signal.

(InsertD)

TS3.5.2

SR3.5.2.7 Verifyeachvalvecreditedforautomaticallyisolatinga penetrationflowpathactuatestotheisolationpositionon anactualorsimulatedactuationsignal.

24months

RCIC System 3.5.3 RIVER BEND 3.5-10 Amendment No. 81, 156 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 means High Pressure Core Spray System is OPERABLE.

AND A.2 Restore RCIC System to OPERABLE status.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months 14 days B.

Required Action and associated Completion Time not met.

B.1 Be in MODE 3.

AND B.2 Reduce reactor steam dome pressure to 150 psig.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 36 hours

, RPV WATER INVENTORY CONTROL,

Primary Containment-Shutdown 3.6.1.10 RIVER BEND 3.6-31 Amendment No. 81, 119 3.6 CONTAINMENT SYSTEMS 3.6.1.10 Primary Containment-Shutdown LCO 3.6.1.10 Primary containment shall be OPERABLE.

APPLICABILITY:

During movement of recently irradiated fuel assemblies in the primary containment.

During operations with a potential for draining the reactor vessel (OPDRVs).

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

Primary containment inoperable.

A.1 Suspend movement of recently irradiated fuel in the primary containment.

AND A.2 Initiate action to suspend OPDRVs.

Immediately Immediately

Primary Containment Air Locks 3.6.1.2 RIVER BEND 3.6-3 Amendment No. 81, 85 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, During movement of recently irradiated fuel assemblies in the primary containment,.

During operations with a potential for draining the reactor vessel (OPDRVs).

ACTIONS

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

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.

2.

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 containment air locks with one primary containment air lock door inoperable.

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

1.

Required Actions A.1, A.2, and A.3 are not applicable if both doors 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)

Primary Containment Air Locks 3.6.1.2 RIVER BEND 3.6-6 Amendment No. 81, 85 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C.

(continued)

C.3 Restore air lock to OPERABLE status.

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

Required Action and associated Completion Time of Condition A, B, or C not met in MODE 1, 2, or

3.

D.1 Be in MODE 3.

AND D.2 Be in MODE 4.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 36 hours E.

Required Action and associated Completion Time of Condition A, B, or C not met during movement of recently irradiated fuel assemblies in the primary containment or OPDRVs.

E.1 Suspend movement of irradiated fuel assemblies in the primary containment.

AND E.2 Initiate action to suspend OPDRVs.

Immediately Immediately

PCIVs 3.6.1.3 RIVER BEND 3.6-14 Amendment No. 81 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. (continued)

D.3 Perform SR 3.6.1.3.5 for the resilient seal purge valves closed to comply with Required Action D.1.

Once per 92 days E.

Required Action and associated Completion Time of Condition A, B, C, or D not met in MODE 1, 2, or 3.

E.1 Be in MODE 3.

AND E.2 Be in MODE 4.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 36 hours F.

Required Action and associated Completion Time of Condition A, B, C, or D not met for PCIV(s) required to be OPERABLE during MODE 4 or 5.

F.1 Initiate action to suspend OPDRVs.

OR F.2 Initiate action to restore valve(s) to OPERABLE status.

Immediately Immediately 1

CRFA System 3.7.2 RIVER BEND 3.7-5 Amendment No. 81 119 132, 154 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 inoperable for reasons other than Condition B.

A.1 Restore CRFA subsystem to OPERABLE status.

7 days B.

One or more CRFA subsystems inoperable due to inoperable CRE boundary in MODE 1, 2, or 3.

B.1 Initiate action to implement mitigating actions.

AND B.2 Verify mitigating actions ensure CRE occupant exposures to radiological, chemical, and smoke hazards will not exceed limits.

AND B.3 Restore CRE boundary to OPERABLE status.

Immediately 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months 90 days (continued)

CRFA System 3.7.2 RIVER BEND 3.7-6 Amendment No. 81 119 132 154 185 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C.

Required Action and Associated Completion Time of Condition A or B not met in MODE 1, 2, or 3.

C.1

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

LCO 3.0.4.a is not applicable when entering MODE 3.

Be in MODE 3.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months D.

Required Action and associated Completion Time of Condition A not met during movement of recently irradiated fuel assemblies in the primary containment or fuel building or during OPDRVs.

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

LCO 3.0.3 is not applicable.

D.1 Place OPERABLE CRFA subsystem in emergency mode.

OR D.2.1 Suspend movement of recently irradiated fuel assemblies in the primary containment and fuel building.

AND D.2.2 Initiate action to suspend OPDRVs.

Immediately Immediately Immediately E.

Two CRFA subsystems inoperable in MODE 1, 2, or 3 for reasons other than Condition B.

E.1

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

LCO 3.0.4.a is not applicable when entering MODE 3.

Be in MODE 3.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

CRFA System 3.7.2 RIVER BEND 3.7-7 Amendment No. 81 119 132 154 165 168, 183 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F.

Two CRFA subsystems inoperable during movement of recently irradiated fuel assemblies in the primary containment or fuel building, or during OPDRVs.

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

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

AND F.2 Initiate action to suspend OPDRVs.

Immediately Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.2.1 Operate each CRFA subsystem for 15 continuous minutes.

31 days SR 3.7.2.2 Perform required CRFA filter testing in accordance with the Ventilation Filter Testing Program (VFTP).

In accordance with the VFTP SR 3.7.2.3 Verify each CRFA subsystem actuates on an actual or simulated initiation signal.

24 months (continued)

Control Room AC System 3.7.3 RIVER BEND 3.7-9 Amendment No. 81 119 132 185 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 subsystem inoperable.

A.1 Restore control room AC subsystem to OPERABLE status.

30 days B.

Two control room AC subsystems inoperable.

B.1 Verify control room area temperature 104°F.

AND B.2 Restore one control room AC subsystem to OPERABLE status.

Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months 7 days C.

Required Action and Associated Completion Time of Condition A or B not met in MODE 1, 2, or 3.

C.1

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

LCO 3.0.4.a is not applicable when entering MODE 3.

Be in MODE 3.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

Control Room AC System 3.7.3 RIVER BEND 3.7-10 Amendment No. 81 119, 132 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D.

Required Action and associated Completion Time of Condition A not met during movement of recently irradiated fuel assemblies in the primary containment or fuel building, or during OPDRVs.

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

LCO 3.0.3 is not applicable.

D.1 Place OPERABLE control room AC subsystem in operation.

OR D.2.1 Suspend movement of recently irradiated fuel assemblies in the primary containment and fuel building.

AND D.2.2 Initiate action to suspend OPDRVs.

Immediately Immediately Immediately (continued)

Control Room AC System 3.7.3 RIVER BEND 3.7-11 Amendment No. 81 119 132, 168 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E.

Required Action and associated Completion Time of Condition B not met during movement of recently irradiated fuel assemblies in the primary containment or fuel building, or during OPDRVs.

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

AND E.2 Initiate action to suspend OPDRVs.

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

24 months

Distribution SystemsShutdown 3.8.10 RIVER BEND 3.8-41 Amendment No. 81, 132 3.8 ELECTRICAL POWER SYSTEMS 3.8.10 Distribution SystemsShutdown LCO 3.8.10 The necessary portions of the Division I, Division II, and Division III AC, DC, and Division I and II AC 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 containment or fuel building.

ACTIONS

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

LCO 3.0.3 is not applicable CONDITION REQUIRED ACTION COMPLETION TIME A.

One or more required AC, DC, or AC vital bus electrical power distribution subsystems inoperable.

A.1 Declare associated supported required feature(s) inoperable.

OR A.2.1 Suspend CORE ALTERATIONS.

AND A.2.2 Suspend movement of recently irradiated fuel assemblies in the primary containment and fuel building.

AND Immediately Immediately Immediately (continued)

Distribution SystemsShutdown 3.8.10 RIVER BEND 3.8-42 Amendment No. 81 ACTIONS CONDITIONS REQUIRED ACTIONS COMPLETION TIME A.

(continued)

A.2.3 Initiate action to suspend operations with a potential for draining the reactor vessel.

AND A.2.4 Initiate actions to restore required AC, DC, and AC vital bus electrical power distribution subsystems to OPERABLE status.

AND A.2.5 Declare associated required shutdown cooling subsystem(s) inoperable and not in operation.

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

7 days 3

4

AC SourcesShutdown 3.8.2 RIVER BEND 3.8-18 Amendment No. 81, 132 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 required feature(s) with no offsite power available from a required circuit inoperable.

OR A.2.1 Suspend CORE ALTERATIONS.

AND A.2.2 Suspend movement of recently irradiated fuel assemblies in the primary containment and fuel building.

AND A.2.3 Initiate action to suspend operations with a potential for draining the reactor vessel (OPDRVs).

AND Immediately Immediately Immediately Immediately (continued)

AC SourcesShutdown 3.8.2 RIVER BEND 3.8-19 Amendment No. 81, 132 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

(continued)

A.2.4 Initiate action to restore required offsite power circuit to OPERABLE status.

Immediately B.

LCO Item b not met.

B.1 Suspend CORE ALTERATIONS.

AND B.2 Suspend movement of recently irradiated fuel assemblies in primary containment and fuel building.

AND B.3 Initiate action to suspend OPDRVs.

AND B.4 Initiate action to restore required DG to OPERABLE status.

Immediately Immediately Immediately Immediately C.

LCO Item c not met.

C.1 Declare High Pressure Core Spray System and Standby Service Water System pump 2C inoperable.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months 3

3

DC SourcesShutdown 3.8.5 RIVER BEND 3.8-29 Amendment No. 81, 132 ACTIONS

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

LCO 3.0.3 is not applicable CONDITION REQUIRED ACTION COMPLETION TIME A.

One or more required DC electrical power subsystems inoperable.

A.1 Declare affected required feature(s) inoperable.

OR A.2.1 Suspend CORE ALTERATIONS.

AND A.2.2 Suspend movement of recently irradiated fuel assemblies in the primary containment and fuel building.

AND A.2.3 Initiate action to suspend operations with a potential for draining the reactor vessel.

AND A.2.4 Initiate action to restore required DC electrical power subsystems to OPERABLE status.

Immediately Immediately Immediately Immediately Immediately 3

InvertersShutdown 3.8.8 RIVER BEND 3.8-36 Amendment No. 81, 132 3.8 ELECTRICAL POWER SYSTEMS 3.8.8 InvertersShutdown LCO 3.8.8 One Divisional inverter shall be OPERABLE capable of supplying one division of the Division I or II onsite Class 1E uninterruptible AC vital bus electrical power distribution subsystem(s) required by LCO 3.8.10, "Distribution Systems-Shutdown".

APPLICABILITY: MODES 4 and 5, During movement of recently irradiated fuel assemblies in the primary containment or fuel building.

ACTIONS

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

LCO 3.0.3 is not applicable CONDITION REQUIRED ACTION COMPLETION TIME A.

One or more required inverters inoperable.

A.1 Declare affected required feature(s) inoperable.

OR A.2.1 Suspend CORE ALTERATIONS.

AND A.2.2 Suspend handling of recently irradiated fuel assemblies in the primary containment or fuel building.

AND Immediately Immediately Immediately (continued)

InvertersShutdown 3.8.8 RIVER BEND 3.8-37 Amendment No. 81 ACTIONS CONDITIONS REQUIRED ACTION COMPLETION TIME A.

(continued)

A.2.3 Initiate action to suspend operations with a potential for draining the reactor vessel.

AND A.2.4 Initiate action to restore required inverters to OPERABLE status.

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

7 days 3

ML17248A335

Contents

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Subject:

Subject:

Subject:

SUBJECT:

1.0 DESCRIPTION

2.0 ASSESSMENT

3.0 REGULATORY ANALYSIS

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ML17248A335

Text

Subject:

Subject:

Subject:

SUBJECT:

1.0 DESCRIPTION

2.0 ASSESSMENT

3.0 REGULATORY ANALYSIS

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