Text

Amend 76 to License NPF-47,revising TSs by Removing Component Lists from TSs & Relocating to Technical Requirements Manual
	ML20081B779
Person / Time
Site:	River Bend
Issue date:	03/08/1995
From:	Wigginton D; NRC (Affiliation Not Assigned)
To:	;
Shared Package
ML20081B783	List: ML20081B779; ML20081B785;
References
	NUDOCS 9503160355
	Download: ML20081B779 (59)
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1 jw UNITED STATES

'%i B

NUCLEAR REGULATORY COMMISSION.

l WASHINGTON, D.C. 30MHH1001 f

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GULF STATES UTILITIES COMPANY **

i:y CAJUN ELECTRIC POWER COOPERATIVE AND f

ENTERGY OPERATIONS. INC.

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DOCKET NO. 50-458 RIVER BEND STATION. UNIT 1-AMENDMENT TO FACILITY OPERATING LICENSE Amendment No. 76 License No. NPF-47 l

1.

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

A.

The application for amendment by Gulf States Utilities * (the licensee) dated January 14, 1994, as supplemented by letters dated November 10, 1994, and February 8, 1995, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Comission's rules and regulations set forth in 10 CFR Chapter I; B.

The facility will operate in conformity with the application, as.

amended, the provisions of the Act, and the rules and regulations'of the Comission; C.

There is reasonable assurance: '(i) that the activities authorized l

by this amendment can be conducted without endangering the health -

and safety of the public, and (ii) that _such activities will be conducted in compliance with the Comission's regulations; D.

The issuance of this license amendment will not be inimical to the-comon defense and security or to the health and safety of the public; and f

i I

E0I is authorized to act as agent for Gulf States Utilities Company, which has been authorized to act as agent for Cajun Electric Power Cooperative, and has exclusive responsibility and control over the physical construction,

.i operation and maintenance of the facility.

- Gulf States Utilities Company, which owns a 70 percent undivided interest in River Bend, has merged with a wholly owned subsidiary of Entergy t

Corporation. Gulf States Utilities Company wart'h'e surviving company in the merger.

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9503160355 950308 PDR ADOCK 05000458 P

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o' E.

'The issuance of this' amendment is.in accordance with 10 CFR Part 51 of.

the Commission's regulations and' all applicable ~ requirements have been 3

satisfied.

2.

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

amended to read as follows:

(2) Technical Soecifications and Environmental Protection Plan The Technical Specifications contained-in Appendix A, as revised through Amendment No. 76 and the Environmental Protection Plan contained in Appendix B, are hereby incorporated in the license. E01 shall operate i

the facility in accordance with the Technical Specifications and the j

Environmental Protection Plan.

3.

The license amendment is effective as of its date of issuance.

FOR-THE NUCLEAR REGULATORY COMMISSION David'L. Wi ton, Senior Project Manager Project Directorate IV-1 i

. Division of Reactor Projects III/IV Office of Nuclear Reactor Regulation l

Attachment:

Changes to the Technical Specifications Date of Issuance: March 8, 1995 l

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' ATTACHMENT'TO LICENSE AMENDMENT NO. '76 -

FACILITY OPERATING LICENSE NO.'NPF-47 DOCKET NO. 50-458 b

l

, Replace the following pages of,the Appendix 'A Technical Specifications with..

1 p

the attached pages. The revised pages are identified by Amendment number and

~

contain marginal lines indicating the areas of change. The corresponding overleaf pages are also provided to maintain document completeness.

MMQY1 INSERT l

.i xxv xxv.

XXVi XXVi 1-6 1 :

3/4 3-1 3/4 3-1 3/4 3-7 3/4 3-7 3/4 3-9 3/4 3-9

[

3/4 3-11 3/4 3-11 3/4 3-12 3/4 3-12 3/4 3-13 3/4 3-13 3/4 3-14 3/4 3 3/4 3-15 3/4 3-15 3/4 3-16 3/4 3-16 3/4~3-18 3/4 3-18 3/4 3-25'

.3/4 3-25 3/4 3-26 3/4 3-26 3/4 3-27 3/4 3-27 3/4-3-29 3/4 3-29 j

3/4 3 3/4 3-30 3/4 3-30a 3/4 3-30a 3/4 3-41 3/4 3-41>

3/4 3-42 3/4 3-42 3/4 3-43 3/4'3 t 3/4 3-107 3/4 3-107 3/4 3-111 3/4.3-11 3/4 4-11 3/4 4-11 3/4 4-12 3/4 4-12 3/4 4-13 3/4 4-13 3/4 4-22 3/4 4-22 l

3/4 4-24 3/4 4-24 l

3/4 6-3 3/4 6-3 3/4 6-4 3/4 6-4 3/4 6-5 3/4 6 ;

3/4 6-6 3/4 6-6 3/4 6-7 3/4 6-7 3/4 6-31 3/4 6-31 i

3/4 6-31a 3/4 6-31a 3/4 6-32 thru 3/4 6-32 1

3/4 6-47 3/4 6-51 3/4 6-51 3/4 6-52 3/4 6-52

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c 3/4 6-53.:

_3/4 6-53:

3/4 6-54_

-3/4l6-54 3

3/4 8-25;

3/4 8 W..

13/4 8-26 3/4 8 -

3/4.8-28.thru.-

/4_8-28 3

c4 3/4 8-32, 3/4.8-33 3/4-8-33.

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3/4 8-34 3/4.8 3/4 8-36 3/4_8-36-.

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^*i s i INDEX l LIST OF: TABLES'(Continued)

TABLE TITLE EASE 3.3.7.4 Remote' Shutdown Monitoring. Instrumentation ~.... 3/4 3-77:

3.3.7.4-2 Remote Shutdown System Controls.......... 3/4 3-78 I

-4.3.7.4-1

. Remote Shutdown Monitoring Instrumentation -

3/4 3-80

.[

c Surveillance Requirements.............

t 3.3.7.5-1 Accident Monitoring Instrumentation........ 3/4 3-82~

j 4.3.7.5-1 Accident Monitoring Instrumentation Surveillance Requirements 3/4 3-84 3.3.7.8-1 Fire Detection Instrumentation 3/4 3-88 t

3.3.7.10-1 Radiation Liquid Effluent Monitoring-Instrumentation.................. 3/4'3-95 4.3.7.10-1 Radioactive Liquid Effluent Monitoring Instrumentation Surveillance Requirements..... 3/4 3-97 3.3.7.11-1

. Radioactive Gaseous Effluent Monitoring Instrumentation................'..~ 3/4 3-100' l

4.3.7.11-1 Radioactive Gaseous Effluent Monitoring Instrumentation Surveillance Requirements..... 3/4 3-103

~

'3.3.9-1 Plant Systems' Actuation Instrumentation...... 3/4 3-108:

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3.3.9-2 Plant Systems Actuation Instrumentation l

Setpoints........_..._........... 3/4 3-110 4

4.3.9.1-1 Plant Systems Actuation Instrumentation Surveillance Requirements............. 3/4 3-111 3.4.3.2-1 DELETED.......-............... 3/4 4-13 3.4.3.2-2 DELETED...................... -3/4 4-13

'3.4.4-1 Reactor Coolant System Chemistry Limits...... 3/4 4-17 4.4.5-1 Primary Coolant Specific Activity Sample and Analysis Program 3/4 4-20 4.4.6.1.3-1 DELETED...................... 3/4 4-24 i

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RIVER BEND - UNIT 1 xxv Amendment No. 76 1

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INDEX y

, LIST OF TABLES (Continued)

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i TABLE TITLE EAGE i

i 3.6.1.3-1.

DELETED..........=._............- 3/4'6-7

'3.6.4-1 DELETED................'..........

3/4~6-32 f

3.6.5.3-1 DELETED..-..-......-............

3/4 6-53' 3.7.6.4-1 Fire Hose Stations.:...............

3/4 7-27.

L Yard Fire Hydrants and Associated Hydrant Hose U ~

3.7.6.5-1 Houses 3/4 7-29 g,

3 '. 7. 8-1 Area Temperature Monitoring............

3/4 7-33 1

n 3.7.10-1 Total Predicted Settlements............

3/4 7-36 3.7.10-2 Allowable Differential Senlements of Major Structural Interface Points............

3/4 7-37 4.8.1.1.2-1 Diesel Generator Test Schedule 3/4 8-11 4.8.2.1-1 Battery Surveillance Requirements.........

3/4 8-1.

3.8.4.1-1 DELETED......................

3/4 8-28 3.8.4.2-1 DELETED......................

3/4 8-34.

4.11.1.1.1-1 Radioactive Liquid Waste Sampling and Analysis Program......................

3/4 11-2 4.11.2.1.2 Radioactive Gaseous Waste Sampling and-Analysis Program..................._...

3/4 11-8 l

3.12.1-1 Radiological Environmental Monitoring Program...

3/4 12-3 i

3.12.1-2 Reporting Levels for Radioactivity Concentrations in Environmental Samples 3/4 12-9 4.12.1-1 Detection Capabilities for Environmental Sample Analysis 3/4 12-10 B 3.2.1-1 Significant Input Parameters to the Loss-of-Coolant Accident Analysis.................

B 3/4 2-3 1

1 RIVER BEND - UNIT 1 xxvi Amendment No. 76 i

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c, DEFINITIONS je;

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of~a logic circuit, from sensor through and including"the actuated device, to; verify.0PERABILITY. The LOGIC SYSTEM FUNCTIONAL TEST may be performed by any 1 series cf: sequential, overlapping or total system steps shch that the-entire logic system is. tested.

MEMBER (S) 0F THE PUBLIC 1.25., MEMBER (S) 0F THE PUBLIC shall include all persons who are not occupa-l j

tionally associated with the plant. This category does not include employees-'

of the utility, its contractors or vendors.

Also excluded from this category i

are persons who enter the s',te to service equipment'or to make deliveries. '

l This category does include persons who use portions of the site for recreational :

occupational or other purposes not associated with the plant.

6 MINIMUM CRITICAL POWER RATIO 1.26 The MINIMUM CRITICAL POWER RATIO (MCPR) shall be the smallest CPR which l

exists in the core.

i 0FFSITE DOSE CALCULATION MANUAL (ODCM)

-1.27 The OFFSITE DOSE CALCULATION' MANUAL shall contain the methodology and-

.l parameters used in the calculation of offsite doses due to radioactive gaseous-and liquid effluents and in the calculation of gaseous and liquid effluent monitoring alarm / trip setpoints.

It:shall also contain a table and figure defining current radiological environmental monitoring sample locations.

- OPERABLE - OPERABILITY j

1.28 A system, subsystem, train, component or device shall be OPERABLE or

.l have OPERABILITY when it is capable of performing its specified function (s)

I and when all necessary attendant instrumentation, controls,' electrical power, J

cooling or seal water, lubrication or other auxiliary equipment that are

.1 requireo'for the system, subsystem, train, component or device to perform.-its j

function (s)'are also capable of performing their related support function (s).

OPERATIONAL CONDITION - CONDITION

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3

-1.29 An OPERATIONAL CONDITION, i.e., CONDITION, shall be any one inclusive l

combination of mode switch position and average reactor coolant temperature as

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specified in Table 1.2.

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i PHYSICS TESTS -1.30 PHYSICS TESTS shall be those tests performed to measure the fundamental l

. nuclear' characteristics of the reactor core and related instrumentation and 1).

described in Chapter 14 of the FSAR, 2) authorized under the provisions of'10 CFR 50.59,-or 3) otherwise approved by the Commission.

RIVER BEND - UNIT 1 1-5 Amendment No. 42

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' IDEFINITIONS I t

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PRESSURE B0UNDARY LEAKAGE

-l s1.31 PRESSURE BOUNDARY LEAKAGE:shall^ be leakage through 'a.non-isolableifault c in a reactor coolant system component. body, pipe wall or vessel: wall.

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l PRIMARY CONTAINMENT INTEGRITY -~ FUEL ~ HANDLING 1

i 1.32 PRIMARY CONTAINMENT INTEGRITV'- FUEL. HANDLING'shall. exist when: ~

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A11' primary containment penetrations. required to be closed.during:

il) accident: conditions are closed by at least one manual valve, blind flange, or deactivated.au',omatic valve: secured in.its closed' l

position.

Up to twelve vont and; drain line pathways may be opened:

under administrative control for the purposes of, surveillance -

testing provided the total calculated flow rate through the' open 1

vent and drain line. pathways is less. than or equal to 70.2' cfm.

'l b.

All primary containment hatches are closed.

j c.

Each primary containment air lock is'in compliance with the requirements of Specification 3.6.1.4.

PRIMARY CONTAINMENT INTEGRITY - OPERATING t

1.33 PRIMARYxCONTAINMENT INTEGRITY - OPERATING shall exist when:

l a.

.All primary containment penetrations required to be closed during-1.

j accident conditions are either:

1.-

Capable of being closed by an OPERABLE containment' automatic:

isolation system, or

.j 2.

Closed by at least one' manual valve, blind flange, or deacti.--

vated automatic valve secured in its: closed position, except

.i as provided in Specification 3.6.4.

b.

All. primary containment. equipment hatches are closed and sealed.

-l 4

c.

'Each primary containment air. lock is in compliance with the

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requirements of Spec _ification 3.6.1.4.

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d.

The primary containment leakage rates are within the' limits ofo l

j Specification 3.6.1.3.

l e.

The suppression pool is in compliance with the requirements of l

Specification 3.6.3.1.

j f.

The sealing mechanism associated with each primary containment j!

penetration; e.g., welds, bellows or 0-rings, is OPERABLE ~.

PROCESS CONTROL PROGRAM (PCP)

-1.34 The PROCESS CONTROL PROGRAM shall contain the current formula, sampling, analyses, tests, and determinations to be made to ensure that the processing 1

and packaging of solid radioactive wastes based on demonstrated' processing of.-

actual. or simulated wet solid wastes will be accomplished in such a way as to i

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t assure compliance with 10 CFR Part 20, 10 CFR Part 61, 10 CFR Part 71 and j

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'I RIVER BEND

' UNIT 1 1-6 Amendment No. Sh4h76 j

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[yg, -(3/4.3 INSTRUMENTATION ~

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43/4 1 1 REACTOR PROTECTION SYSTEM INSTRUMENTATION:

2

~ I LIMITING CONDITION FOR OPERATION 4

.3;3.11<As'a" minimum, the reactor protection' system instrumentation channils M i

4 showniin1 Table 3.3.1-1 shall' be OPERABLE..

j APPLICABILITY:1 As shown. in TableL.3.1-1.

3 3

a l'

ACTION-1

a. ~.With' one channel required by Table l3.3.1-liinoperablefin 'one or more?

d Functional Units, place the inoperable channel and/or that.. Trip d

System in the tripped condition

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

o b... With two or more channels required by Table 3.3.1-1; inoperable in l

yl one or more Functional Units;

- + Ji L1.

Within one hour,. verify sufficient channels remain OPERABLE l -

a

i or in the tripped condition

to maintain trip capability in d

the Functional Unit, and q

+

2.

.Within six hours, place. the' inoperable' channel (s) in one Trip System and/or that Trip System ** in the tripped j

condition *, and j

.t 3.

Within'12' hours, restore the. inoperable channels in the a

other Trip System to an OPEF:ABLE status or place the l

inoperable channels in.the tripped condition *.

Otherwise, take the ACTION required by Table' 3.3.1-1 for the a

Functional Unit.

1 d

. SURVEILLANCE REOUIREMENTS 4.3.1.1. Each reactor protection system instrumentation channel ~shall be -

demonstrated OPERABLE by the performance of the CHANNEL CHECK,- CHAitNEL 1

FUNCTIONAL TEST and CHANNEL CALIBRATION operations,for the OPERATIONAL' q

-CONDITIONS and at the frequencies.shown in Table 4.3.1.1-1.#-

l 4.3.1.2 LOGIC SYSTEM FUNCTIONAL TESTS and simulated automatic operation of all. channels'shall. be performed at least once per 18 months.

l 4.3.1.3 THE REACTOR PROTECTION SYSTEM RESPONSE TIME of each required reactor trip functional unit shall'be demonstrated to be within its limit at least once per~18 months. Neutron detectors are: exempt'from. response.. time testing.-

1 Each test :shall include at least one. channel' per trip system such that all

- channels'are tested at least once every N times 18 months.where N is the total:

. number of redundant channels in a specific reactor trip system.

An' inoperable channel or Trip System need not' be placed in the tripped '

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condition where this would cause the Trip Function to occur.

In thess cases, if the inoperable channel:is not restored to OPERABLE status within the required time, the ACTION required by Table 3.3.1-1 for that Functional.

Unit shall be taken.

.l

- This. Action applies to that Trip System with the most inoperable channels; j

if both Trip Systems have the.same number of inoperable channels, the

~ ACTION can-be applied to either Trip System.

Channel Calibration' period may be extended as identified by notesJ'o' and

'q' on Table 4.3.1.1-1.

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RIVER BEND - UNIT 1 3/4 3-1 Amendment No. 0,i7,72,73,70,76 j

3 tar' E 3.3.1-1 i

j REACTOR PRottCil0F SYSTEM IN51RIPfN!A!!ON.

to APPI18ARIE MINIMIM-OPLRA IONAL DPtRABli CllANNELS FUNCTIONAL UNIT CO_ND' ' 10NS PER TRIP SYSTEM (a)

ACTION 1.

Intermediate Range Monitors:

-4 a.

Neutron Flux - High 2

3 1

w 3(b)4 3

2-5 3

3 b.

Inoperative 2

3 1

3, 4

'3

_2-5 3

3 IC):

2.

Average Power Range Monitor a.

Neutron Flux - High, Setdown 2

3 1

}

3 3

2 i

5(b)4 3

.3

?

A b.

Flow Blased Simulated Thermal Power - High 1

'3 4

1 c.

Neutron Flux - High' 1

3 4'

Inoperative 1, 2 3

1

3. 4 3

2 5

3 3

3.

Reactor Vessel Steam Dome

~ Pressure - High 1,2(d) 2 1

4.

Reactor Vessel Water Level.- Low, i

Level 3 1, 2 2~

1 5.

Reactor Vessel Water level-High, I,)

g Level-8 4

6.

Main Steam Line Isolation Valve -

Closure

~g(e) 4 10 7.

Main Steam Line Radiation -

~~

High 1, 2(d) 2.

5 8.

Dryg11 Pressure - High

~1, 2II) 2.

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TABLE 4.3.1.1-1 REACTOR PROTECTION SYSTEN' INSTRUMENTATION SURVEILLANCE REQUIREMENTS

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CHANNEL OPERATIONAL 5 CHANNEL FUNCTIONAL CHANNEL-CONDITIONS IN WHICH:

FUNCTIONAL UNIT:-

CHECK TEST CALIBRATION (*)

SURVEILLANCE REQUIRED 1

1. Intermediate Range Monitors:

a.

Neutron Flux - High S/U,S,(b)

S/U(*),. W R

.2!

S W

R 3,4,5 -

b.

Inoperative NA W

'NA-2,3,4,5^

+-

2. Average Power Range Monitor:")

a.

Neutron Flux - High, S/U,S,(b)

S/U(*), W.

SA 2

Setdown S

W SA 3,"4, 5 b.

Flow Biased Simulated-Thermal - Power - High '

S,D(h)

S/U(*), Q W(d'(3,SA(3,R"3 -

1-d'

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c.

Neutron Flux.- High S

S/U!*), Q W(d), SA 1

d.

.-Inoperative

.NA Q

-NA

1,2,3,~4,1SS

3. Reactor. Vessel Steam Dome Pressure -.High S

Q R(*

1, : 2(1) l-

4. Reactor Vessel Water Level -

Low, level 3-

'S.

Q R(* -

- 1,! 2 L

5. Reactor Vessel Water Level -

High,- Level 8 -

S Q

R(*

.1-6.- Main Steam Line ' Isolation

~

-R.

~ 1.

i Valve - Closure NA-Q

7. Main Steam Line' Radiation -

High:

' S' Q

.R.

'1,'2(38'

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8. Drywell-Pressure - High-

'S-

~ Q-R(8-1, 2"8 l

RIVER BEND

, UNIT'l 3/4 3-7.-

Amendment' No. 2,",9,K,,76 :

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- - - -.. -. -. ~ ~.... -.

,...... - -. _... _.. -, - -,..... - - -,,., -.. ~ -. - -.. - -. - -... - - -.. - +. -.. ~..... -

- + -.... -. -.

. - =

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' TABLE 4.3.1.1-l'(Continued)

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REACTOR PROTECTION' SYSTEM INSTRUMENTATION SURVEILLANCE REQUIREMENTS

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CHANNEL L OPERATIONAL 1 l

CHANNEL-FUNCTIONAL CHANNEL-

' CONDITIONS IN WHICH

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FUNCTIONAL UNIT CHECK TEST CALIBRATION SURVEILLANCE REQUIRED

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9. Scram Discharge Volume Water Level --High a.

Level Transmitter S

Q-R(')(P) 1, -. 2,. 5(*) :

b.

Float Switch NA Q

R

~ 1, 2, 5(")

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10. Turbine Stop' Valve - Closure

-S(")

Q(")-

R('"") ~

h

1. -

11. Turbine Control Valve Fast Closure,-Trip 011-j.

Pressure - Low S!")

Q(.")

R(8"") ~

1.

12. Reactor Mode Switch Shutdown Position NA R-NA 2 1, 2, 3,-4, 5

13. Manual Scram NA-W NA

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2, 3,'4,'5l Ll:'

(a)

Neutron detectors may be excluded from CHANNEL CALIBRATION.

(b) _ ~ The IRM and SRM channels shall be determined to overlap for at least 1/2 decade _during each startup..

after. entering:0PERATIONAL: CONDITION 2 'and the IRM and APRM channels shall be determined.to. overlap at least-l/2. decade during each controlled shutdown, if not performed within'the previous 7 days., ;for; (c)

Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months prior to startup, if not performed within the previous 7 days.

-(d)

This calibration shall consist -of:the adjustment of the APRM channel to conform to the power. values.

calculated by a heat' balance'during'0PERATIONAL. CONDITION 1:when THERMAL POWER 125% of RATED THERMAli POWER. Adjust the APRM channel if-the absolute difference is greater than 2% of RATED.THERMALLPOWER.

~

Any-APRM channel ' gain' adjustment' made -in' compliance with Specification 3.2.2 Lshall not: be : included.in.-

. determining the absolute difference.

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(e)

This calibration shall consist of the' adjustment of the APRM flow biased channel to conform to,a calibrated flow ' signal.

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RIVER BEND ' UNIT 1-3/4 3-87 Amendment'No. Mr74 L 4.

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JTABLE4.3.1.1-1(Continued)'[

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REACTOR PROTECTION SYSTEM INSTRUMENTATION SURVEILLANCE REQUIREMENTS

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(f)

The LPRMs.shall be calibrated at least once per '1000 effective full power hours.(EFPH)iusing the TIP? -

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4 system.

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(g)

Calibrate'Rosemount trip unit setpoint at least once per 92 days

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(h).. Verify measured drive flow to-be'less than or equal to establishad drive flow:at the existing' flow - -

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control valve position.

(1)

This calibration'shall consist of verifying the simulated thermal power time = constant'is within.the limits specified in the COLR.

(j)

This function is not required 'to be operable when the reactor pressure vessel head is removed..per-Specification 3.10.1.

c

' ~

(k)

With'any control rod withdrawn. Not applicable ~ to control rods. removed per.'_ Specification-3.9.10.1 or, 3.9.10.2.

(1)

This function is not, required to be OPERABLE when DRYWELL INTEGRITY:is not required per Specifica--

tion 3.10.1.

~

(m)

Verify the Turbine Bypass. Valves are closed when THERMAL POWER is greater than.or. equal to 40f RATED' ~

THERMAL POWER.

(n)

The CHANNEL FUNCTIONAL: TEST and CHANNEL CALIBRATION shall include the turbine firstfstage_ pressure.-

i.

instruments.

(o)

The CHANNEL CALIBRATION.shall exclude the flow reference transmitters; these transmitters:shall be; calibrated at least once'per.18 months.-

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RIVER BEND - UNIT: 3/4 3 _ j Amendment No.E 3,*,'2,'2,7',76 :

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INSTRUMENTATION 3/4.3.2 ~ ISOLATION ACTUATION INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.2 The isolation actuation instrumentation channels shown in Table 3.3.2-1 shall be OPERABLE with their trip setpoints set consistent with the values shown in the Trip Setpoint column of Table 3.3.2-2.

l APPLICABILITY: As shown in Table 3.3.2-1.

ACTION:

a.

With an isolation actuation instrumentation channel trip setpoint less conservative than the value shown in the' Allowable Values column of Table 3.3.2-2, declare the channel inoperable'until the channel is restored to OPERABLE status with its trip setpoint adjusted consistent with the Trip Setpoint value.

b.

With the number of OPERABLE Channels less than required by the i

Minimum OPERABLE Channels per Trip System requirements for one Trip _

System, 1.

Within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for Trip Functions 1.b, 2.b, 3.b, 6.c, 6.e, and 6.f, and 2.

Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months for Trip Functions other than 1.b, 2.b, 3.b, 6.c, 6.e, and 6.f, place the inoperable channel (s) and for that Trip ~ System in the l

tripped condition *.

c.

With the number of OPERABLE Channels less than required by the Minimum OPERABLE Channels per Trip System requirements for both Trip

Systems, 1.

Within one hour, place the inoperable channel (s)'in one Trip System and/or that Trip System ** in the tripped condition *, and 2.

Within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for Trip Functions iJ 2.b, 3.b, 6.c, 6.e, and 6.f, and within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months for Trip Fui.. sons other than 1.b, 2.b, 3.b, 6.c, 6.e, and 6.f, place the inoperable channel (s) in the other Trip System in the tripped condition *.

An inoperable channel or Trip System need not be placed in the tripped I

condition where this would cause the Trip Function to occur.

In these cases, if the inoperable channel is not restored to OPERABLE status within the required time, the ACTION required by Table 3.3.2-1 for that Trip i

Function shall be taken.

This ACTION applies to that Trip System with the most inoperable channels; if both Trip Systems have the same number of inoperable channels, the i

ACTION can be applied to either Trip System.

RIVER BEND - UNIT 1 3/4 3-10 Amendment No. U,73,74 h

^

'St ?

INSTRUMENTATION

SURVEILLANCE REQUIREMENTS 4.3.2.1 Each isolation actuation instrumentation channel shal1 be demonstrated OPERABLE by.the performance of the CHANNEL CHECK, CHANNEL FUNCTIONAL TEST and-

-CHANNEL CALIBRATIONLoperations for the OPERATIONAL CONDITIONS and at the frequencies shown in Table 4.3.2.1-1.

l:

o 4.3.2.2 LOGIC SYSTEM FUNCTIONAL TESTS and simulated automatic operation of all channels shall be performed at least once per 18 months.

[

4.3.2.3 The' ISOLATION SYSTEM RESPONSE TIME of each required isolation trip function shall be demonstrated to be within its limit at least once per 18-months.

Each test shall include at least one channel per trip system such that.

all channels are tested at least once every N times 18 months, where N is the total number of redundant' channels in a specific isolation trip system.

n 1

RIVER BEND - UNIT 1 3/4 3-11 Amendment No. S,72,73,76 l'

1 TABLE 3.3.2-1 ISOLATION ACTUATION-INSTRUMENTATION-MINIMUM APPLICABLE OPERABLE CHANNELS OP2 RATIONAL TRIP FUNCTION PER TRIP SYSTEM

CONDITION ACTION

1. FRIMARY CONTAINMENT ISOLATION

a. Reactor Vessel Water le el-Low Low, Level - 2'*"*" '

2 1,2,3

- 20

b. Drywell Pressure - High'b)(*"3' 2

' 1, 2, 3

. 20

c. Containment Purge Isolation 1

1,2,3 21 Radiation - High

2. MAIN STEAM LINE ISOLATION

a. Reactor Vessel Water Level-Low Low Low, Level 1.

2 1,2,3 20

b. Main Steam Line Radiation - High")

2 1,2,3 23

~

c. Main Steam Line Pressure - Low 2

1 24

d. Main Steam Line Flow - High 2/MSL 1, 2, 3 :

. 23

e. Condenser Vacuum - Low 2

1, 2**, 3**

23

f. Main Steam Line Tunnel Temperature High 2-1, 2, 3 23

g. Main Steam Line Tunnel A Temperature - High 2

1,2,3 23

h. Main Steam Line Area Temperature High.(Turbine Building) 2/ area'

. 1, 2, 3 23 RIVER BEND - UNIT 1 3/4 3-12

~ Amendment No. S b76 re.

.v.,

-. - + -

, < = -

--..--rw

.r---

-~M v

=vE4 9 --

.m-

..w-r-*E~-

=

<-rw5

.w,--.

c+.cm-..

w---.E- -

ys

.g

~

s

% g;pg g- <

-.o 1

x TABLE 3.3.2-l'(Continued) 1 ISOLATION ACTUATION INSTRUMENTATION.

APPLICABLE MINIMUM OPERABLE CHANNELS OPERATIONAL-TRIP FUNCTION PER TRIP SYSTEM (*)

-CONDITION

' ACTION

3. SECONDARY CONTAINMENT ISOLATION a.ReactorVesselWaterLeve}I")

Low Low, level 2(""*"*"

2

'1, 2, 3

'.251

b. Drywell Pressure - High(bHc)(e)(hMI) 2 1, 2, 3 25:

c. Fuel' Building Ventilation Exhaust Radiation - High(e)(h) 28 d.ReactorBuildingAnnulusVentilp) tion Exhaust Radiation - High(""'"

1-1, 2, 3 -

29

4. REACTOR WATER CLEANUP SYSTEM ISOLATION

a. A Flow - High 1

' 1,. 2,- 3 27

b. A F1ow Timer 1

1, 2,_3

- 27^

c. Equipment Area Temperature -

High-1 1, 2, _ 3

27

d. Equipment Area A Temperature --

High 1;

1, 2, 3 ~

27:

e. Reactor. Vessel Water Level -

Low Low,--Level 2

'2 1, 2; 3 27 -- -

f. Main-Steam Line Tunnel-

~

Ambient Temperature.High

_1

~1, 2, 3

27. -

~

RIVER BEND - UNIT 1

'3/4 3-13 AmendmentLNo. Wr76_-

~

m-wwA--.--

'_mmt m e-el rw e --rsyw idus+--'Te e-.erw w

-1sweM4-ari-tw-m w

-w--

ig

-mav*arywpe smegw m

.. _,.,m

- TABLE 3.3.2-1 (Continued).

4 ISOLATION ACTUATION INSTRUMENTATION h

MINIMUM APPLICABLE:

OPERABLE CHANNELS OPERATIONAL

^

TRIP FUNCTION PER TRIP SYSTEM (*)

CONDITION ACTION

4. REACTOR WATER CLEANUP SYSTEM ISOLATION (Continued)

g. Main Steam Line Tunnel A' Temperature - High 1

1,2,3 27

h. SLCS-Initiation 1")

1, 2, 3 27..

5. REACTOR CORE ISOLATION COOLING SYSTEM ISOLATION

a. RCIC Steam Line Flow - High 1

1, 2,.3 27

b. RCIC Steam Line Flow - High Timer 1

1, 2, 3 27~

' c. RCIC Steam Supply Pressure Low

!=

1, 2, ' 3 27

d. RCIC Turbine Exhaust Diaphragm Pressure - High 2-1, 2,'3 27

e. RCIC Equipment Room Ambient Temperature - High 1

1, 2, 3 27~

f. RCIC Equipment Room A-Temperaturej-High 1

1, 2, 3 27

g. Main' Steam Line Tunnel-Ambient Temperature - High

.1 1, 2,.3' 27

h. Main Steam Line Tunnel A Temperature - High:_

1 1,. 2, 3

'27l t-RIVER BEND - UNIT 1 3/4 3 Amendment ' No. 76 -

_+---.___,-...._e-e

. +,..

+

,,v'.>

n--- +. -

-w-

+

.sv.3 e

,,,e---

=

--e

+. w

,,,,..s

.., -, 's5

- - +..

,e ie, m.

.2 m--r v---

~,]~,.

J_]F :

[1-n.

_ y.

?

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i 19 i[p,pp

^

j; >-M n

'h'

' ylh

~g-a;.

Q.

+

-W,'g~

;w j

1

TABLE 3.3.2-1_(Continued)L

s '

w j.y

~

ISOLATION ACTUATION INSTRUMENTATION.

y! ' :

a: ;f; MINIMUM APPLICABLE:

~

S, OPERABLE; CHANNELS -

'OPERATIONALi TRIP FUNCTION

-PER TRIP SYSTEM"

CONDITION ~

' ACTION dr

.m m

'5.

REACTOR CORE ISOLATION

~ $.,

COOLING SYSTEM ISOLATION-(continued) i1 g

1. Main Steam Line Tunnel i

Temperature Timer

. 1 1, 2, ~ 3 527-J. RHR Equipment Room Ambient

_l'.

. 1, 2, 3-27:

%~ ~

~ Temperature - High

^"

k. RHR EquipmentLRoom

.' 27

Temperature - High' 1

1, 2, 3

1. RHR/RCIC Steam Line Flow -

~

-High-1 1, 2, 3 <

27.(

cw _,

m. Drywell Pressure -:High")

' 1-1, 2,; 3 -

27).

n. Manual = Initiation"'

1 1,- 2,~ 3 ?

J26:

Jf

6. RHR SYSTEM ISOLATION m

+

a. RHR Equipment 2 Area Ambient

~

Temperature - High' 2

1,~2,'3:

30 (

b. RHR. Equipment Area A L m

Temperature:- High

-2~

1, 2,-3.

30~

1

[

c. Reactor Vessel Water

. 1,. 2, ' 3 0

?302~

m Leveli-Low,z level 3 12-

~

d. Reactor Vessel:. Water Level

-,((

Low Low Low,? Level 1"

.2-1,<2,-3>

-'30 s.

t, s

4 y:

RIVER BEND - UNIT 1

3/4 3-15!

-s 1 Amendment:No. 76, s

I b.

u.

x;;

f!

~

s i. ' -

w

.m

..,,.... m a Ja, J..

J.

, W;.

l'

- ~- "

~

r

--__-_,........-,-2

.m

.. m L

..A..~.,.,_..._m

.-.,..J-.....,,s..b...,

=.g m.

-- m -

a['Wl

..< %g; j ;.

g-

2

^

y;

+

! TABLE'3.3.2-1-(Continued) y'

. ISOLATION ACTUATION' INSTRUMENTATION

~

- MINIMUM' APPLICABLE-.

OPERABLE CHANNELS OPERATIONAL

- TRIP FUNCTION PER TRIP SYSTEM")

CONDITION ACTION

6. RHR SYSTEM ISOLATION (continued)

e. Reactor Vessel (RHR Cut-in

^

Permissive) Pressure -

High 2

1,:2, 3 30.

f. Drywell Pressure - High 2

I,.2, 3..o

7. MANUAL INITIATION"

2-1,.2, 3

22 ~

~

he

~.

"M e

RIVER BEND - UNIT-1;

' 3/4'3 Amendmen't)No.76l

' ~~

~

~-

.47 g i 4

j

%[.

r.

.,,,-.---.,,--sr-ie - w A.

-m

.-.., -, e m,' w.

-.4

..e-.#v.r-...w,,,

e.

U.,. d ',-m A,,

.,w-b...

..'---vvm-,y w

.w,..'.vw-

.we,.

,e

[s_

~ !

t

' *lt

)

TABLE 3.3.'2-1 (Continued)

ISOLATION ACTUATION INSTRUMENTATION' ACTION Be'in at least HOT SHUTDOWN within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN ACTION 20 within the next 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

e ACTION 21 -

Close the affected system isolation valve (s) within one. hour or be in at least HOT SHUTDOWN within the next 12' hours and in-COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

l Restore the manual initiation function to OPERABLE status within ACTICN 22 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in at least HOT SHUTDDWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and -in COLD SHUTDOWN within the following 24. hours.

Be in at least STARTUP with the associated isolation valves ACTION 23 closed within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months or be in at least HOT SHUTDOWN wittiin 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the next 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

. 4 Be in at least STARTUP'within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

AC11CN 24 Within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months , establish SECONDARY CONTAINMENT INTEGRITY -

ACTION 25 OPERATING with the standby gas treatment system.and Fuel

' Building Ventilation System (emergency mode) operating.

Restore the manual initiation function to OPERABLE status ACTION 26 within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months or close the affected system isolation valves within l' hour and declare the affected system inoperable.

j ACTICN 27 -

Close the affected system isolation valves within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and declare'the affected system inoperable.

I Within I hour, initiate and maintain the Fuel Building Ventilation ACTION 28 System in the emergency mode of operation.

I Within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months , initiate and maintain annulus mixing system with ACTION 29 the reactor building annulus exhaust to at least one operating standby gas treatment train.

J Within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months , lock the affected system isolation valves closed ACTION 30 and declare the affected system inoperable.

i i

i RIVER BEND - UNIT 1 3/4 3-17

~

i TABLE 3.3.2-1 (C:ntinued)

ISOLATION ACTUATION INSTRUMENTATION ACTION l

NOTES I

When handling irradiated fuel in the Fuel Building.

l

- May be. bypassed with reactor mode switch not in Run and all turbine stop valves closed.

.(a)

A channel may be placed in an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for required surveillance without placing the trip system in the tripped condition provided at least one other OPERABLE channel in the same trip system is monitoring that parameter.-

i (b)

Also actuates the standby gas treatment system.

(c)

Also actuates the main control room air conditioning system in the emergency mode of operation..

(d)

Also trips and isolates the air removal pumps.

(e)

Also ' actuates secondary containment ventilation isolation dampers.

l (f)

Manual initiation of SLCS pump C001B closes 1G33*M0VF001, and manual initiation of SLCS pump C001A closes 1G33*MOVF004.

(g)

Requires RCIC system steam supply pressure-low coincident with drywell pressure-high.

(h)

Also starts the Fuel Building Exhaus6 Filter. Trains A and B.

(i)-

Also starts the Annulus Mixing System.

(j)

Also actuates the containment hydrogen analyzer / monitor recorder.

(k)

Manual initiation isolates the outboard steam supply isolation valve only and only following a manual or automatic initiation of the RCIC system.

(1)

Valve IE22*MOVF023 does not' isolate on the manual initiation.

i L

f

?

r i

RIVER BEND - UNIT 1 3/4 3-18 Amendment No. 74,76 l

I f,

..-*p

, :.t c,-

.w g,3n-t 4*

. 'l',

p

R.i...

-,+

- y, ' 7.

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)

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)

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w. ; *

., A :-

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...,k

,'y

(_

i

)l, c,

- Table 3.3.2-3 has been deleted.

c.

j y,

.. d:

rr -

y.

5 4

n

,?

J

< u. *

.f t

-'f

,a"{',-'

r P

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6 t'

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. l L

1 9

. i R]VER BEND - UNIT 1 3/4 3-25 Amendment No. M,73 l

1 0

- e i

. - +,,

=

9

y TABLE 4.3.2.1-1 N~

1 ISOLATION ACTUATION INSTRUMENTATION SURVEILLANCE REQUIREMENTS CHANNEL OPERATIONAL ~~

CHANNEL FUNCTIONAL CHANNEL CONDITIONS'IN WHICH TRIP UNIT CHECK TEST CALIBRATION SURVEILLANCE REQUIRED' O

1. PRIMARY CONTAINMENT ISOLATION

~

a. Reactor Vessel Water level -

Low Low Level 2 5

Q R

1, 2,'3 l~

b. Drywell Pressure - High S
~Q R(b' 1, 2, 3
c. Containment Purge Isolation Radiation - High S
Q R
1, - 2, 3
2. MAIN STEAM LINE ISOLATION
a. Reactor Vessel Water Level -
Low Low Low Level 1 S
Q R(b) 1, 2, 3
b. Main Steam Line Radiation -
High S
Q R
l',
2, 3 l
c. Main Steam Line Pressure -
Low S
_ Q Rcb>
3
d. Main Steam Line Flow -'High S
Q R(b) 1, 2, 3 1
e. Condenser Vacuum - Low S
Q R(b' 1,'2**, 3**
f. Main Steam Line Tunnel Temperature - High-S Q
R-1, 2, 3
g. Main Steam Line Tunnel ATemperature - High.
S Q
R
-1,.2, 3
h. Msin Steam Line Area S
Q
.R(b) -
1, 2, ' 3
-Temperature-High-(Turbine Buildingi RIVER BEND -; UNIT 1 3/4 3-26' Amen'dment No. 8,9, 7U6 -
g
- - + _ -..,...,., -, -. - - - -.
....,.. -... -,. - ~,,,,.,... - -

.-.,-~----_-..,-,.<,.----.----.--..~,,--.,.,.,..-.,.,,sw

m.
am ; e,;w>
~~
z...
TABLE'4.3.2.1-11(Continued) 7 ISOLATION ACTUATION INSTRUMENTATION SURVEILLANCE REQUIREMENTS 1 if CHANNEL LOPERATIONAL
J-CHANNEL FUNCTIONAL CHANNEL-CONDITIONS 2IN WHICH:-
,~
J TRIP UNIT ~
CHECK TEST' CALIBRATION SURVEILLANCE REQUIRED
~ ~ ~
3. SECONDARY-CONTAINMENT ISOLATION
a. Reactor Vessel-Water Level - Low' Low Level 2 S
Q R*'
1,3 2,.~ 3

i
b. Dryweil Pressure - High S.
Q R(b)
/
2, 3 I
c. Fuel Building Ventilation Exhaust Radiation - High S
Q R.
d. Reactor Building Annulus Ventilat!on Exhaust
~ 1,. 2, -. 3 Radiation - High' S
Q R-
4. REACTOR WATER CLEANUP SYSTEM ISOLATION
a. A Flow - High
-S Q
R.
- 1, 2, 3 L l
I
b. A Flow Timer NA
'Q Q
1,. 2, - 3 d:
c. Equipment Area Temperature -
High'~
S-Q.
R 1,. 2, 3.
{,
d. Equipment Area'
~
A Temperaturei-High
.S-
-Q R
le 2, 3 l:
e,-Reactor Vessel ~ Water Level - Low Low Level 2=
S
-Ql R(b)
'1,12, 3
')..
i Temperature - High S
.. ~ -
f.. Main Steam Line Tunnel Ambient
.R "1,?2,'3 l
Q-l
g. Main Steam Line Tunnel
-A Temperature - High'
.S
-Q:
.R 1, 2,:3
-.]?
h. SLCS Initiation ~
NA Q
NAi 1,12,.3:
l.
N
~
. Amendment No. *,72,N,76 '
RIVER BEND - UNIT 1 3/4f3-27:
+
_ _ _ _ _ _ _ _ _ _ _ _ _ _.. _. _ _ _ _..... ~.... +, _.... -,.
-.,_.....,..ab.._._...,...,,.,
..,_..,,,,,a.,
-, ~~
, ~
gg., g,g
fa, Q:
_,, _ ^
^
~
TABLE 4'.3.2l111/(Contiinued))'
1 ~,iJ
.d
'E 3
l
'3
. ISOLATION-ACTUATION INSTRUNENTATION SURVEILLANCE REQUIRENENTS<
-.;; ~
CHANNEL
. OPERATIONAL 4
. CHANNEL FUNCTIONALs CHANNEL CONDITIONS 1IN WHICH:i TRIP UNIT CHECK TEST CALIBRATION SURVEILLANCE REQUIRED' 6
5. REACTOR CORE ISOLATION COOLING SYSTEN ISOLATION-'
-a. RCIC Steam Line Flow - High-S Q-
'R(b)'
fl,2,3 l~
b. RCIC. Steam Line Flow-High. Timer-NA
.Q Q
-1, 2,:3 El
c. RCIC Steam Supply Pressure -
. Lo.s -
S' Q-R(b)
1; s 2,^ 3
jC
'd. RCIC Turbine. Exhaust Diaphragm Pressure - High-S Q
R(b)
% 2i 3
-b.
e.-RCIC Equipment Room Ambient Temperature - High S
Q R.
1l 2, 3 5l-
f. RCIC Equipment' Room A Temperature - High S
Q R.
1, 2, 3
l J
g. Main Steam Line Tunnel Ambient Temperature - high S
Q-R 1,2,[3 Jl.
h. Main Steam Line Tunnel A Temperature
.High S.
Q R
-1, 2, 3
-l-
i. Main Steam Line Tunnel
. l^ '
Teq>erature Timer -
NA.-
Q
'Q 1, 2, 3 1
j. RHR Equipment Room Ambient
.Rl
...1, = 2, 3
~ h; Temperature' "High S
-Q
~
k. RHR' Equipment' Room A.
-6 l
Temperature - High S
Q:
R
.-1, 2, 3 F
1. RHR/RCIC Steam Line Flow-High
.S :
Q.
R'b' 1,l2,'3 l-i
m. Drywell Pressure-High S
-Q
..' R(b' 1, 2, 3
~
n. Manual Initiation _
NA-R'
.NA-
=1 ? 2,. 3 '
^
RIVER BEND - EUNIT 1:
3/4 3-28 i Amendment No. 74 -
.____,_,__,,_.._._,_,,__,,a..,
u __,,;;,....__
, _' g 3
)
^
i q.
j.e.;
TABLE 4.3.2.1-1 (Continued)'
ISOLATION ACTUATION INSTRUNENTATION SURVEILLAMCE REQUIRENENTS-j CHANNEL-OPE'RATIONALL CHANNEL
-FUNCTIONAL CHANNEL
- CONDITIONS IN WHICH TRIP UNIT
~ CHECK TEST CALIBRATION' SURVElli.ANCE REQUIRED :
6. RHR SYSTEN~ ISOLATION
~
a. RHR Equipment Area Ambient Temperature'- High S
Q R
1, 2, 3 '
.g 9
b. RHR Equipment Area a Tempera'ure - High S
Q R
1, ' 2, 3
c. Reactor' Vessel Water Level -
Low Level 3 S
Q
-Rcb>
1, 2, 3
d. Reactor Vessel Water Level -
Low. Low Low Level 1 S
Q R(6) l1, 2, 3 =
e. Reactor Vessel (RHR Cut-in-Permissive) Pressure - High S
.Q-R(b> ~
l1; 2, 3
f. Drywell Pressure ^ :High S-Q R(b)-
~ 1, 2, 3 -
~
7. MANUAL INITIATION:
LNA' Q
NA' 1,.2,3L
When handling' irradiated fuelTin the Fuel Building.
When:the reactor. mode switch is in.Run and/or any turbine stop valve is.open.
(a) Each train or logic channel'.shall be tested at least every other. 92' days.
(b) Calibrate trip unit setpoint at least:once per 92 days.
l RIVER BEND - UNIT =l' 3/4 3 ' Amendment No..",",72,75,76 L
E
x
.r.;
INSTRUMENTATION i
w S
' 3/4.3.3 EMERGENCY CORE COOLING' SYSTEM ACTUATION INSTRUMENTATION-l
~
LIMITING CONDITION FOR OPERATION 3.3.3 The' emergency core cooling system'(ECCS) actuation instrumentation j
channels shown in Table.3.3.3-1 shall be OPERABLE with their' trip setpoints set
.i l consistent with the values shown in the Trip Setpoint column of Table 3.3.3-2. -
APPLICABILITY:: ' As shown in' Table 3.3.3-1.
H
" LAWQN:
-l
a. With an ECCS' actuation instrumentation channel trip'setpoint less.
f conservative than the value shown _ in the Allowable Values column. of Table ~
3.3.3-2, declare the channel inoperable until. the channe1<is restored to OPERABLE status with its trip setpoint adjusted consistent with the Trip i
^
Setpoint value.
'l
b. With one or more ECCS actuation instrumentation channels inoperable, take i
the ACTION required by Table 3.3.3-1.
~
c. With either ADS trip system."A" or "B" inoperable, restore the inoperable trip system to OPERABLE status:
l 1
1.
Within 7 days, provided that the HPCS and RCIC systems are OPERABLE,
(;
or 2.
Within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , provided either the HPCS or the RCIC system ~is i
inoperable.
1 Otherwise, be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and reduce reactor steam dome pressure to less than or equal to 100 psig
.)
within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .
j SURVEILLANCE REQUIREMENTS 4.3.3.1 Each ECCS actuation instrumentation channel. shall be demonstrated OPERABLE'by the performance of the CHANNEL CHECK,. CHANNEL FUNCITONAL TEST and l
CHANNEL CALIBRATION operations. for the OPERATIONAL CONDITIONS and at the
. frequencies shown in Table 4.3.3.1-1.
l 4.3.3.2 1.0GIC SYSTEM FUNCTIONAL TESTS and simulated' automatic operation of.all i
channels shall be performed at least once per 18 months.
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l lq RIVER BEND - UNIT 1 3/4 3-30 Amendment No. 9,72,73,76 l
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INSTRUMENTATION j3/4.3.3 EMERGENCY CORE COOLING' SYSTEM ACTUATION INSTRUMENTATION:
SURVEILLANCE REOUIREMEITIS
~
4.3.3.3 At least once per 18 months,.the ECCS RESPONSE TIME of each required
-l c-ECCS trip function shall be demonstrated to be within the limit. Each test shall: include at least one channel per tri a system such that_ all ~ channels are tested at least once every N times 18 montis, where N is the total number of..
l' redundant channels in a specific ECCS trip system.
L RIVER BEND - UNIT 1 3/4 3-30a Amendment No. 0,72,73,76
m py r=,
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i TABLE 4.3.3.1-l'
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~
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EMERGENCY' CORE COOLING SYSTEM ACTUATION-INSTRUMENTATION SURVEILLANCE REOUIREMENTS 4
CHANNEL OPERATIONALE CHANNEL FUNCTIONAL CHANNEL-
" CONDITIONS FOR WHICH3 TRIP FUNCTION:
CHECK TEST CALIBRATION SURVEILLANCE REQUIRED A. DIVISION I-TRIP'SYSTEN
1. RHR-A fLPCI MODE) AND LPCS SYSTEN a.
Reactor-Vessel Water Level--
Low Low Low Level 1 S
Q R(*)
1,.2,.3,-4*, 5*
b.
Drywell Pressure - High S
Q-R(*)
1, 2, 3 c.
LPCS Pump Discharge: Flow-Low S
Q R(
1,-2,.3, 4*, 5*
d.
Reactor Vessel-Pressure-Low S
Q R(
1,'2, 3, 4*, 5*J
'(LPCS/LPCI Injection Valve.
Permissive)
e..LPCI Pump A. Start Time Delay-
~e
Relay - _
NA<
Q Q(
1,-2,.3,_4*, 5*
a f.
LPCI Pump A Discharge Flow-Low S Q
R 1, 2, 3, 4*, 5*
4 2
g.
LPCS Pump Start Time Delay.
- NA-Q' Q
1,-2,- 3, 4*, 5*
l Relay
h. -Nanual Initiation NA R
NA 1, 2, 3, 4*,-5*
17g
2. AUTOMATIC DEPRESSURIZATION SYSTEN TRIP SYSTEM "A"#
a.
Reactor Vessel' Water Level Low Low Low, Level 1.
S Q
R(
'1,-2, 3-f b.: Drywell; Pressure-HfghL S-Q R(*)
1, 2,13 -
c.
ADS Timer.
NA Q
-Q
<1,.-2, 3 d.
Reactor Vessel Water Level -
Low' Level 3
.S Q-R(
c 1, 2, -
e.
LPCS Pump Discharge Pressure-High S
- Q '-
'R(*)
l', 2, 3 I
f.
LPCI~ Pump A Discharge
. Pressure-High S
.. Q.
R(*)
.1, 2,'3._
g. : ADS Drywell Pressure Bypass
.NAi Q;
Q-
- 1, :;2, 3. -
f; Timer h.
ADS NanualeInhibit Switch "NA-
-Q:
' NA --
l',; 2, 3
i. D Nanual Initiation NA-
't :-
NA
~.1,h2,3
~ RIVER BEND -' UNIT-1 3/4:3-41, Amendment-No. ",72, ?i,76 i 3
4 c=
=
=
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s TABLE'4.3.3.1-1:(Continued)
EMERGENCY CORE COOLING SYSTEM ACTUATION INSTRUMENTATION SURVEILLANCE' REQUIREMENTS
'1
~ CHANNEL
.OPERATIONAli
~
CHANNEL
' FUNCTIONAL' CHANNEL CONDITIONS.FOR'WHICH TRIP FUNCTION CHECK TEST CALIBRATION SURVEILLANCE REOUIRED B. DIVISION II TRIP SYSTEM
1. RHR B AND C (LPCI MODE) a.
Reactor Vessel Water Level -
Low Low Low Level 1 S
Q
'R(*)
1,.2,.3, 4*, 5*'
b.
Drywell Pressure.- High.
S Q
R(*)
11, 2,_3 c.
Reactor Vessel Pressure-Low.
S Q
R(*) -
1,' 2,^3,-4*,
5*'
(LPCI-Injection Valve Permissive) d.
LPCI' Pump B Start Time Delay Re1ay '
NA Q
- Q(*) '
1, 2, 3,14*,.5*'
l e.
LPCI. Pump Discharge Flow-Low S'
Q R
1,'2, 3,.4*, 5*:
f.
LPCI Pump C Start Time Delay NA Q
Q-
-1, 2,'3, 4*, 5*
Relay g.
Manual Initiation NA R
NA 1,_2,L3,4*,:5*.
[.
2. AUTOMATIC DEPRESSURIZATION' SYSTEM _
TRIP SYSTEM "B"#
a.
Reactor Vessel Water level --
Low Low Low. Level.1 S
Q
'R(*)
1, 2, 3 -
- b.
Drywell Pressure -'High S
Q R(*)-
1,-.2, 3
c.
ADS Timer NA
-Q Q
1,. 2,~. 3.
d.
ReactorzVessel Water Level -
Low Level 3-S Q
'R(*)
1, - 2, 3 e..
LPCI' Pump'B and.C Discharge Pressure-High S
Q R(*) -
1, 2, 3 f.
ADS Drywell Pressure Bypass-
,= NA.
Q..
Q
.1,. 2,. 3 '
Timer:
g.. ADS Manual InhibitL Switch NA-Q lNA.
1,-2,L3-
. h. ' Manual Initiation NA-R
.NA'
.1, 2,:3 RIVER. BEND - UNIT 1 3/4 3-42 Amendment No'. ",72, 7061
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TABLE 4.3.3.1-1 (C;ntinued)
EMERGENCY CORE COOLING SYSTEM ACTUATION INSTRUMENTATION SURVEILLANCE REOUIREMENTS~
CHANNEL OPERATIONAL CHANNEL FUNCTIONAL CHANNEL CONDITIONS FOR WHICH-TRIP FUNCTION CHECK TEST-cal,IBR* TION SURVEILLANCE REQUIRED C. DIVISION III TRIP SYSTEM
1. HPCS SYSTEM a.
Reactor Vessel Water Level -
Low Low Level 2 S
Q R(*)
1, 2, 3, 4*, 5*
b.
Drywell Pressure-High S
Q.-
R'*)
1, 2, 3 c.
Reactor Vessel Water Level-High Level 8 S
Q R(*)
1, 2, 3, 4*, 5*
d.
Condensate Storage Tank level -
Low S
Q R(*)
1, 2, 3, 4*, 5*
e.
Suppression Pool Water Level - High S
Q R(*)
1, 2, 3, 4*, 5*
f.
Pump Discharge Pressure-High S
Q R(*)
1, 2, 3, 4*, 5*
g.
HPCS System Flow Rate-Low S
Q R(*)
1, 2, 3, A*, 5*
l h.
Manual Initiation NA R
NA 1, 2, 3,
, 5*
D. LOSS OF POWER
1. Divisions I and II a.
4.16 kv Standby Bus Under-S M
R 1, 2, 3, 4**, 5**
l voltage (Sustained Under-voltage) b.
4.16kv Standby Bus Under-S M
R 1, 2, 3, 4**, 5**
l voltage (Degraded Voltage)
2. Division III a.
4.16 kv Standby Bus Under-S NA R
1, 2, 3, 4**, 5**
voltage (Sustained Under-voltage) b.
4.16kv Standby Bus Under-S H
R 1, 2, 3, 4**, 5**
voltage (Degraded Voltage)
Not required to be OPERABLE when reactor steam dome pressure is less than or equal to 100 psig.
When the system is required to be OPERABLE per Specification 3.5.2.
Required when ESF equipment is required to be OPERABLE.
(a) Calibrate trip unit setpoint at least once per 92 days.
RIVER BEND - UNIT 1 3/4 3-43 Amendment No. 9,72, 74,76
~.
c.
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l
.(*
INSTRUMENTAY10N c-t 3/4.3.4 RECIRCULATION PUNP TRIP ACTUATION INSTRUNENTATION ATWS RECTRCULATION PUMP TRIP SYSTEN INSTRUMENTATION l
J:J{MITING CONDITION FOR OPERATION I3.3.4.1 The anticipated transient without scram recirculation pump trip '(ATWS-RPT) system instrumentation channels'shown.in Table 3.3.4.1-1 shall'be OPERABLE:
with their trip setpoints set consistent with values shown in the Trip Setpoint-i column of Table 3.3.4.1-2.
l APPLICABILITY: OPERATIONAL CON 0! TION 1; j
ACTION:
a.
With an ATWS-RPT system instrumentation channel trip setpoint less conservative than the value shown in the Allowable Values column of Table 3.3.4.1-2, declare the channel inoperable until the channel is restored to OPERABLE status with the channel trip setpoint adjusted.
consistent with the Trip'Setpoint value.
b.
With the number of OPERA 8LE channels one less than required by the Minimus, OPERA 8LE Channels per Trip System requirement for one or.-
both trip systems, restore the inoperable channel to OPERABLE status within 30 days or be in at least STARTUP within the.next 5 hours5.787037e-5 days 0.00139 hours 8.267196e-6 weeks 1.9025e-6 months .',
c.
Otherwise, restore at least one inoperable channel in each trip system.to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in at least STARTUP j
within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .
l SURVEILLANCE REQUIREMENTS 4.3.4.1.1 Each ATWS-RPT system instrumentation channel shall be demonstrated OPERABLE by the perfomance of the CNANNEL CHECK, CNANNEL FUNCTIONAL TEST, and CHANNEL CALIBRATION operations at the frequencies shown in Table 4.3.4.1-1.'
4.3.4.1.2 LOGIC SYSTEM FUNCTIONAL TESTS and simulated automatic operation of all channels shall be performed at least once per IS months.
d RIVER SEND - UNIT 1 3/4 3-44 i
i m,.
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INSTRUMENTATION
'1/4.3.9 PLANT SYSTEMS ACTUATION INSTRUMENTATISH LIMITING CONDITION FOR OPERATION 3.3.9' The plant systems actuation instrumentation channels shown in
-i Table 3.3.9-1 shall be OPERABLE with the',e trip setpoints set consistent.with -
the values shown. in the Trip Setpoint column of Taole 3.3.9-2.
APPLICABILITY: As shown in Table 3.3.9-1.
4 ACTION:
i
a. With a plant system actuation instrumentation channel trip setpoint less conservative than the value shown in the Allowable Values column of' Table 3.3.9-2, declare the channel inoperable and take the ACTION required by Table 3.3.9-1.
b. With one or more plant systems actuation instrumentation channels inoperable, take the ACTION required by Table 3.3.9-1.
SURVEILLANCE RE0VIREMENTS l
4.3.9.1 Each plant system actuation instrumentation channel shall be demonstrated OPERABLE by the performance of the CHANNEL CHECK, CHANNEL FUNCTIONAL TEST and CHANNEL CALIBRATION operations for the OPERATIONAL CONDITIONS and at the frequencies shown in Table 4.3.9.1-1.
l 4.3.9.2 LOGIC SYSTEM FUNCTIONAL TESTS and simulated automatic operation of all channels shall be performed at least once per 18 months.
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RIVER BEND - UNIT 1 3/4 3-107 Amendment No. 9 74 76 7 7 i
7 c,
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9 54 A kj 3
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TABLE 3.3.9-1 H
y PLANT ~ SYSTEMS ACTUATION INSTRUMENTATION-l-
' MINIMUM-APPLICABLE.
~
OPERABLE CHANNELS-
0PERATIONAL-TRIP FUNCTION
- PER TRIP SYSTEM
CONDITIONS ACTIONL T
i
1. PRIMARY CONTAINMENT VENTILATION SYSTEM -
UNIT COOLER A AND B-
a. Drywell Pressure-High E
' 1,~2, 3
-150'
b. Containment-To-Annulus AP High 3
1, 2,;3=
151
c. Reactor Vessel Water Level-Low Low Low Level 1 2
-1, 2,' 3
-150.
d. Timers 1-
. 1, 2,~3-152 c.
2. FEEDWATER SYSTEM / MAIN TURBINE TRIP SYSTEM
a. Reactor VesseliWater Level-High Level 8 3
1 153-
's b
(a)
- A channel may be placed'in an. inoperable status--lfor up to-6 hour's:: for. required surveillance without.
placing the. TRIP SYSTEM in the tripped condition, provided"attleast one other. OPERABLE l channel;in the ggi same TRIP SYSTEM is monitoring that parameter.
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i RIVER BEND - UNIT ;3/4 3-108
Amendment No. 74l-a e
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.. r, TABLE 4.3.9.1-1 3
PLANT SYSTEMS ACTUATION INSTRUMENTATION SURVEILLANCE REQUIREMENTS CHANNEL OPERATIONAL.
CHANNEL FUNCTIONAL CHANNEL CONDITIONS IN WHICH TRIP FUNCTION CHECK TEST-CALIBRATION SURVEILLANCE REOUIRED'
1. PRIMARY CONTAINMENT VENTILATION SYSTEM -
UNIT COOLER A AND B
a. Drywell Pressure-High D
Q R(*)'
1, 2, 3
b. Containment-to-Annulus AP.High D
Q R(')
1, 2, 3
c. Reactor. Vessel Water Level-Low Low Low Level 1 D
Q R(*)
1, 2, 3
d. Timer NA Q
R 1, 2, 3
2. FEEDWATER SYSTEM / MAIN TURBINE TRIP SYSTEM
a. Reactor Vessel Water Level-High Level 8 D
Q R
l-(l (a) Calibrate trip unit setpoint once per 92-days.
RIVER BEND _ UNIT 1 3/4 3-111 Amendment No. 9,72,7',76-i
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REACTOR COOLANT SYSTEM 7
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M OPERATIONAL LEAKAGE ew-4
.NQ
! LIMITING: CONDITION FOR OPERATIOND
^
[ 33 M.3.2 Reactor coolant ' system 1eakage sh'all be -limited to:
l
^
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a' No PRESSURE BOUNDARY. LEAKAGE.
bt !5fgpa UNIDENTIFIrl LEAKAGE.
g
.c.
- 25 gpm total leakage (averaged over any124-hour period).-
j d.-
0.5 gpm per. nominal' inch of valve; size _ up toia ' maximum of 5 gpm-i
d leakage at a reactor coolant system pressure;of 1025 1-_15 psig from' e
any reactor, coolant system pressure isolation-valve.:
$,, ll
.2 le.
2 gpm UNIDENTIFIED' LEAKAGE-increase within any period of 24' hours or ' '
o, 2.
less (Applicable in OPERATIONAL' CONDITION 1< only).
~
j r
4 APPLICABILITY: OPERATIONAL CONDITIONS.1, 2 and 3 7
' j j
ACTION:
a.
With any PRESSURE BOUNDARY LEAKAGE, be in,athleast HOT SHUTDOWN 1
within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN-within the next'24; hours..
j 3
b.-
With any reactor coolant. system leakage' greater: than' the limits in bj d
~
'and/or c, above,-reduce the leakage rate to within.the limits within 4 hour4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months s-or be in at least HOT SHUTDOWN within the next.12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 7and; i
in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .
i With' any~ reactor coolant system pressure isolation: val' eileak$ge: _.
c.
v
- greater than~ the above limit, isolate the high pressure: portion'off c
l the affected system from the low pressure: portion:within:4 hours by' l
. use of-at least two other. closed manual, deactivated automatic.or;~
check
valves,.or be:in at 1 east-HOT! SHUTDOWN withinithe'next j
12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and.in COLD SHUTDOWN.withinLthe following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .
d.
With one or more of the high/lew pressurefintsrface' valve leakage.
pressure monitors inoperable, restore the inoperable monitor (s) to l
l OPERABLE status within 7 days or-' verify the.. pressure to.be less thanL l
the alarm point at.least once per.12. hours;: restore the inoperable-j monitor (s) to OPERABLE status'within 30 days'or be in at least HOT 1
SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ;and COLD SHUTDOWN within the-1 following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .. The provisions of: Specification 3.0.4 are: notf j
1 applicable.
e..
With any reactor coolant system UNIDENTIFIED LEAKAGE; increase.
i greater than the limits in e.,
above,.within.4' hours. identify the source of leakage as 'not IGSCC susceptible material or; be. in ati least HOT SHUTDOWN within the'next ". hours and'in. COLD SHUTDOWN.
'1
= within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .
Which have been verified not to exceed ~the5 allowable leakage limit at the 9
last refueling outage or after the last time the valve was disturbed, ll whichever is more recent.
y
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RIVER BEND - UNIT-1 3/4 4-11 Amendment No. 67r76
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LSURVEILLANCE REQUIREMENTS ~
i I
'4:4.3.2.1 The reactor. coolant system leakage shall be demonstrated to be 9
4
within-'each of the above. limits by

:
a'.
' Moni tori ng the. drywell ' atmospheri c : parti cul ate rad i oacthity at l f
least once. per:12 hours, j
]
b..
Monitoring the. sump. flow rates at.least 'once~ per112 hours,..
~
a y
c.
Monitoring the:drywell. air coolers condensate. flow; rate atileast l
once per 12: hours, and 3
j m
d.
Monitoringithe reactor vessel head flange Lleak' detection-system at :
a least once per. 24-hours.-
~
4.4.3.2.2 'Each reactor. coolantc system pressure isolation valve shall be.
l.-
'I demonstrated OPERABLE by -leak testing pursuant to Specification-4'.0.5 1
including paragraph :IWV-3427(B) oflthe ASME Code and.the RBS Inservice Test-1 Program and verifying. the leakage of-each valve; to be within'the; specified i
limit.
j
- The provisions of Specification 4.0.4 ~ are not applicable' for entry into.
3
- OPERATIONAL CONDITION 3.
~
~4;4.3.2.3 The:high/ low pressure interface valve leakage' pressure monitors
~
shall be demonstrated OPERABLE by performance of. a:
1l:; _ 4
- a.
CHANNEL FUNCTIONAL TEST at least once' per 31 days, and -
. b.
. CHANNEL. CALIBRATION at least once per 18 months.-
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RIVER BEND
. UNIT 1 3/4 4 Amendment No. 7,57,71,76 u
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e 4
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i RIVER BEND - UNIT 1 3/4 4-13 Amendment No. 76
)
I N'
REACTOR COOLANT SYSTEM 3/4.4.4 : CHEMISTRY LIMITING CONDITION FOR OPERATION i
l 3.4.4 The chemistry of the reactor coolant system shall be maintained within the limits specified in Table 3.4.4-1.
APPLICABILITY:
At all times.
1 ACTION:
a.
In OPERATIONAL CONDITION 1:
1.
With the conductivity, chloride concentration or pH exceeding the f
limit specified in Table 3.4.4-1 for less than 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months during one continuous time interval and, for conductivity and chloride F
concentration, for less than 336, hours per year, but with the conductivity less than 10 pmho/cm at 25*C and with the chloride concentration less than 0.5 ppm, this need not be reported to the Commission and the provisions of Specification 3.0.4 are not applicable.
+
2.
With the conductivity, chloride concentration or pH exceeding the limit specified in Table 3.4.4-1 for more than 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months during one continuous time interval or with the conductivity and chloride concentration exceeding the limits specified in Table 3.4.4-1 for more than 336 hours0.00389 days 0.0933 hours 5.555556e-4 weeks 1.27848e-4 months per year, be in at least STARTUP within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .
3.
With the conductivity exceeding 10 pmho/cm at 25*C or chloride concentration exceeding 0.5 ppm, be in at least HOT SHUTDOWN within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the next 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .
b.
In OPERATIONAL CONDITIONS 2 and 3, with the conductivity, chloride con-centration or pH exceeding the limit specified in Table 3.4.4-1 for more than 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months during one continuous time interval, be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , c.
At all other times:
1.
With the:
a)
Conductivity or pH exceeding the limTt specified in Table 3.4.4-1, restpre the conductivity and pH to within the limit within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , or b)
Chloride concentration exceeding the limit specified in Table 3.4.4-1, restore the chloride concentration to within the limit within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , or i
RIVER BEND - UNIT 1 3/4 4-14 i
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REACTOR 'OOLANT SYSTEM
~
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4, q
1 3/4.4.6' PRESSURE / TEMPERATURE LIMITS:
,[
I
' REACTOR COOLANT SYSTEM
' LIMITING CONDITION FOR OPERATION V
b I
3.4.6.1. The reactor coolant system temperature and pressure shall be. limited,
h in accordance with the limit lines shown. on Figure 3.4.6.1-1 (1), curves A and..
A' for ~ hydrostatic or leak testing; (2) curves. B' and' B'. for heatup by non-
' nuclear means, cooldown following.a nuclear shutdown:and low power PHYSICS.
Li TESTS; and (3) curves C and C.' for operations with' a critical. core other thana l
low' power PHYSICS TESTS, with:
i A maximum heatup of 100'F in any one. hour period,.
a.
f b.
A maximum cooldown of 100'F-in any one hour period.
c.
A maximum temperature' change of 10*F in any one hour period during Li inservice hydrostatic and leak testing operations.'above the heatup and cooldown limit curves, and d.
The reactor vessel flange and. head flange' temperature greater,than or equal. to 70'F when reactor, vessel head bolting studs 'are under tension.
j APPLICABILITY:
At all times.
ACTION:
With any of the above -limits exceeded, restore the temperature and/or pressure j
to within the' limits within 30 minutes; perform an engineering evaluation to.
determine.the effects of the out-of-limit condition on the structural integrity
-l of the reactor coolant system; and' determine that the reactor coolant system 1
remains acceptable for continued operations.
Otherwise, be'in at least_ HOT SHUTDOWN within 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months s-and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .
{;
i SURVEILLANCE REQUIREMENTS l
ti 4.4.6.1.1 During system heatup, cooldown and inservice leak and hydrostatic >
i testing operations, the reactor coolant system temperature and pressure,shall.
i be determined, at least once per 30 minutes, Lto be within the above' required
-l heatup and cooldown limits and to the right of the limit lines of-Figure 3.4.6.1-1 curves A and A', B and B', or C and C', as applicable.
j 1
RIVER BEND - UNIT 1 3/4 4-21 a,
p L
i REACTOR COOLANT' SYSTEM
' SURVEILLANCE RE0VIREMENTS (Continued) 4.4.6.1.2 The reactor coolant system temperature and pressure shall be deter-mined to be to' the right of the criticality limit line of: Figure 3.4.6.1-1 curves C and Cwithin 15 minutes prior to the withdrawal of control rods to bring the reactor to criticality and at least.once per 30 minutes'during system heatup.
4.4' 6.1.3.The reactor ' vessel material surveillance specimens shall be removed and examined, to determine changes in reactor l pressure vessel material proper -
ties as required by 10 CFR-50, Appendix H.
The results of these examinations l
shall be used to' update the curves of Figure 3.4.6.1-1.
4.4.6.1.4 The reactor vessel flange and head flange temperature shall be verified to be greater than or equal to 70*F:
a.
In OPERATIONAL CONDITION 4 when reactor coolant system temperature is:
1.
s 100*F, at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .
2.
s 80*F, at least once per 30 minutes.
b.
Within 30 minutes prior to and at least once per 30 minutes during tensioning of the reactor vessel head bolting studs.
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RIVER BEND - UNIT 1 3/4 4-22 Amendment No. 76
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a 200 80LTUP CURWS A',B',C' ARE VAUO
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70'r FOR S EFPY OF OPERATION CURVES A.B.C ARE VAUD FOR 2 EFPY OF OPERATION O
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.600 MINIMUM REACTOR VESSEL METAL TEMPERATURE (*F)
FIGURE 3.4.6.1 - 1 MINIMUM TEMPERATURE REQUIRED VS REACTOR PRESSURE RIVER BEND - UNIT 1 3/4 4-23 AMENDMENT NO. 45
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- RIVER BEND - UNIT 1 3/4 4-24 Amendment No. 4&r76 -
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4 CONTAINMENT SYSTEMS '
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- -1 PRIMARY CONTAlleiENT LEAKAGE 7
1 ILIMITINGCONDITION-FOROPERATION j
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I 3.6;1'.3-Primary containment. leak' age rates shall be. limited to:
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a.
An overall integrated leakage trats of11essTthanfor ' equal tolLa, l
1 O.26 percent.by weight of the primary containment: air per 24-hours j
at.Pa,:7.6 psig.
1 b,
combined leakage rate,of less than 0.60 La forf all penetrations j
and all3 valves' subject to' Type. B and C' tests when pressurized to. '
Pa, 7_.6 'psig.
f i
c.
A leakage rate' of less than:150:scfh for the valves served by each-l Division of MS-PLCS,and a leakage rate of-less than.340. scfh fory
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.each of the valve groups identified below when tested in accordance with.the surveillance-requirements' of 4.6.1.3.f.
1 1
1.
Division I. MS-PLCS Valves and Division LI PVLCS Valves 2.
DivisioniII.MS-PLCS Valves'and Division II PVLCS Valves -
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Division I MS-PLCS-Valves and all first outboard PVLCS Valves d.
A combined leakage rate 'of. less than or equal.to'13,500 cc/hr for f
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all penetrations.that 'are annulus bypass... leakage paths when
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A combined leakage rate of Lless than or equal to 170,000 cc/hr, for all valves that are secondary containment bypass leakage paths j
and equipped with PVLCS, when pressurized to Pa, 7.6 psig.
j a
f.
A combined: leakage rate of less'than or equal to 1 gpm times the j
total number of containment isolation valves in hydrostatically tested lines which penetrate the primary containment, when tested.
.]
at 1.1 Pa, 8.36 psig.
o APPLICABILITY: When PRIMARY CONTAINMENT INTEGRITY-OPERATING is required pe'r l
Specification'3.6.1.1.
j ACTION:
With:
a.
The measured overall integrated primary containment' leakage rate 3
equaling or exceeding 0.75 La, or:
~
j b.
The measured combined leakage' rate, for all penetrations and 'all-valves subject to Type B and.C tests, exceeding 0.60 La, or l
c.
The measured leakage rate greater thar; or equal to.150 scfh for the valves served by each Division of MS-PLCS:or the measured leakage rate greater than or equal to 340 scfh for each valve grouping identified in 3.6.1.3.c.1, 3.6.1.3.c.2 or 3.6.1.3.c.3, or I
r RIVER. BEND - UNIT 1 3/4 6-3 Amendment No. 76 I
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n j.l LIMITING' CONDITION FOR OPERATION (Continuedi l
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ACTION l(Continued) d[,,
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The combined leakage rate, for.'all penetrations that are" annulus
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A1
bypass--leakage paths,iexceeding.13,500'cc/hr,iori 1
1The combined". leakage rate, for all valves thatxare: secondary 1
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containment bypass leakageEpaths and.' equipped'with PVLCS,:
exceeding 170,000 cc/hr, or3 i
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The measured combined leakage rate, for. allfcontainmenti isolation '
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. containment, exceeding'1. gpm times the total n' umber 'of: such J'
h valves..in hydrostatically tested linesswhich penetrate the primary valves,=
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.j a.
The overall integrated leakage rate (s) to less than 0.75' LaLasj applicable, and-1 1
b.
The combined leakage rate, for all penetrations Land:allivalves?
i subject to Type B and.C tests, to less than' 0.60 La,.and -
1 c.
The measured;1eakage rate to less than 150 scfh for the valves.
1 served by each Division.of MS-PLCS and the measured leakage rate!
j to less:than 340 scfh for each of the valve groupings identified 11 in 3.6.1.3.c.1, 3.6.1.3.c.2, and 3.6.1.3.c.3, and.
]y d.
.The combined leakage rate, for.all penetrations that are1 annulus
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d bypass leakage ' paths, to'less than or' equal to 13,500f ec/hr,L and '
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The combined leakage ~ rate, for all valves-that are secondary l-
'd containment bypass leakage paths;and equipped with~ PVLCS,L tolless ?
a than:or equal to 170,000 cc/hr, Land-f.
The combined leakage rate,, for.all containment 1 isolation valves in.
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hydrostatically~ tested-lines which penetrate. the' primary :
f d
containment, to less than or equal to l~ gpm-times zthe total number 1
of such valves,
.ju
' prior to increasing reactor coolant system temperature above 200*F.
l
[j SURVEILLANCE REQUIREMENTS n
L4.6.1.3 The primary containment leakage rates shall beidemonstrAted atLthe j following test schedule and shall be determined in. conformance with the.cri-j a
7 Lteria specified in Appendix J. 'of*10 CFR~ 50 using the methods and provisions of; j
LANSI N45.4:(1972):.
]
a.
Three Type A Overall-Integrated Containment Leakage Rate tests j
shall be conducted at 40
10 month intervals during shuMown: at Pa,- 7.6 psig, during each_10-year service period. The third test-of each set shall-be conducted' during the shutdown for the 10-yearf plant inservice inspection.
RIVER BEND - UNIT 1 3/4 6-4' Amendment ~ No.' 76
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. If any periodic Type _.A. test failsito meeUO.75 Lagtheitest H
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. schedule for subsequent Type A-tests shall: be: reviewed and:
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i approved by the Commission.: JIf two' consecutive Type A tests fail yK i to meet: 0.75 La,' a Type A test shall' be performed at least every,
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=18' months;until: two consecutive Type A tests meet 0.75;La,- at~
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which time the above test schedule may be. resumed.;
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The: accuracy;of each Type A. test. shall be verified by a j
supplemental test which:1 d
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Confirms-the accuracyfof-thel test by verifying that the m
- difference between the supplemental test data and the Type A1 M
' test data is within 0.25 La; The formula to be used is:.~
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[LoJ+LLam - 0.25:La] f Lc s'[Lo + Lam + 0.25.La] where, Lc'- supplemental test results;:Lo = superimposed leakage; Lam - measured Type.A leakage.
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2.
Has duration sufficient to' establish accuratelyL thel change, F
in leakage rate' between the Type A test and the supplemental test.-
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3.
Requires the quantity of gas,- injected into the~ primary :
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containment 1or_ bled;from the primary containment during the supplemental test, to be between 0.75 La and.1.25 La..
d.
Type B and C tests shall be conducted withigas at Pa, 7.6 psig*,._-
ei at intervals no' greater than' 24-months except:forg tests involving:-
l:
Li 1.
Air locks, ll 2.
Main steam positive leakage control; system (MS-PLCS) valves :
and PVLCS valves',
.3.
Penetrations using continuous leakageimonitoring systems,-
1 4.
Primary containment isolation valves !in'hydrostatically _
i tested lines which penetrate the primary containment,1and' j
5.
Purge supply. and exhaust isolation valves-with resilient' material seals.
.e.
Air locks shall be tested and demonstrated'0PERABLE per; 1
Surveillance Requirement '4.6.1.4.
3 f.
Total sealing air leakage. into the primary containment, lat a test:
pressure of 11.5-psid for MS-PLCS valves and 33 psid for-J t'
penetration leakage control-system sealed valves,L shall be determined by test at least once per 18 months. This leakage'may
-. l' be excluded when determining the combined leakage rate, 0.6 La.'
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Unless a hydrostatic test is required.
J RIVER BEND - UNIT 1 3/4 6-5 Amendment No. 7,71,76 1
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CONTAINMENT SYSTEMS C
-SURVEILLANCE REOUIREMENTS iContinuedi f'
g.
Type B tests for. electrical penetrations employing a continuous y
leakage monitoring system shall be conducted at Pa,- 7.6 'psig,.= at intervals no greater than once per 3 years.
h.
Leakage from isolation. valves that are sealed with the PVLCS shall:
' be tested once.per 24. months with the valves pressuri7.ed to at
least.Pa, 7.6 psig. This leakage may be excluded when determining-~
the combined leakage. rate, 0.6 La.
. i '.
Primary containment. isolation valves in hydrostatically tested.
lines which penetrate the primary containment shall be leak tested at least once per 18 months. This leakage may be excluded when determining the' combined leakage rate, 0.6 La.
J.
Purge supply and exhaust isolation valves with resilient material seals shall be tested and demonstrated OPERABLE per. Surveillance -
Requirement 4.6.1.9.3.
k.
.The provisions of Specification 4.0.2 'are not applicable to.
Specifications 4.6.1.3.a. 4.6.1.3.d, 4.6.1.3.g,.and 4.6.1.3.h.
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-l RIVER BEND - UNIT 1 3/4 6-6 Amendment No. N 76 l
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i RIVER BEND - UNIT I 3/4 6-7 Amendment No. 76
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' CONTAIMENT' SYSTEMS :
7
iPRIMARY CONTAI MENT AIR LOCKS.
h N LIMITING CONDITION FOR OPERATION'
' 4.;
Y611.'4 Each primary containment air lock'shell'be OPERABLE with:'
a m'
- BothE doors closed,' exceptL at.least one airL lock doo'r. shall be closed a.
t when-the airnlock is.being used for normal: transit entry and exit through the containment, and g
a b..
An overall air lock leakage rate in compliance with tio limits of-
' Specification 3.6.1.3.d when pressurized to'Pa,.7.6 psig, and;
. c.
The inflatable seal system air flask pressure > 90' psig.
' APPLICABILITY:
OPERATIONAL CONDITIONS 1, 2*, 3, and #.
ACTION:
a.
With one primary containment air lock door in one or both air locks inoperable:
1.
Maintain at least the OPERABLE air lock door closed and either -
restore the inoperable air lock door to OPERABLE status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or lock ~ the OPERABLE air lock door _ closed except as-provided in a.3.
2.
' With an air lock door in only one air-lock inoperable, operation m.y then continue until performance of the next' required overall air lock leakage test" provided that the'0PERABLE air lock door -
zI is verified to be locked closed at-least once per 31 days.'
3.
With one air lock door in~ each air lock inoperable,. operation may then continue with entry and exit permitted-for up to 7 days ** provided that an OPERABLE air lock door. is verified to.
be locked closed after each entry or exit and;an individual, is '
dedicated to assure that two doors in an air lock are not opened simultaneously.
L 4.
Otherwise, in OPERATIONAL CONDITIONS 1,'2, or 3 be in at least'-
HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ..
5.
Otherwise, in Operational Conditlan #, suspend. all ~ operations involving handling'of irradiated fuel in the containment,.
CORE ALTERATIONS, and operations with a potential for' draining
- the reactor vessel.
"See Special Test Exception 3.10.1.
The_ provisions of Specification 3.0.4 are not applicable.
l
When irradiated fuel is being handled in the primary containment and during
CORE ALTERATIONS.and operations with a potential for draining,the reactor.
vessel.
RIVER BEND'- UNIT 1 3/4 6-8 Amendment No. 47
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' CONTAINMENT SYSTEMS 3/4.6.'4 PRIMARY CONTAINMENT ~AND DRYWELL ISOLATION VALVES I
LIMITING-CONDITION FOR OPERATION w
3.6.4 Each primary containment and drywell isolation valve shall be 0PERABLE.
e APPLICABILITY: OPERATIONAL CONDITIONS 1,-2, and 3.
ACTION:
s With one or more of the primary containment or drywell isolation valves inoperable, maintain at least one isolation valve OPERABLE in each affected penetration that is open and, within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months , either:
i a.
Restore the inoperable valve (s) to OPERABLE status, or b.
Isolate each affected penetration by use of at least one deactivated automatic valve secured in the isolated position, and declare the associated system inaperable, if applicable, and l
perform the associated ACTION statements for that system,* or c.
Isolate each affected penetration by use of at least one closed manual valve or blind flange and declare the associated system inoperable, if applicable, and perform the associated ACTION statements for that system.*
Otherwise, be in at least HOT SHUTDOWN within'the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .
j SURVEILLANCE RE0VIREMENTS i
4.6.4.1 Each primary containment or drywell isolation valve shall be l
demonstrated OPERABLE prior to returning the valve'to service, after
-l maintenance, repair or replacement work is performed ~ on the valve or its-i associated actuator, control or power circuit, by cycling the valve through at least one complete cycle of full travel'and verifying the isolation time.
l 4.6.4.2 Each automatic primary containment or drywell isolation valve shall l
be demonstrated OPERABLE during COLD SHUTDOWN or REFUELING at least once per 18 months by verifying that, on an isolation test signal, each automatic l
i isolation valve actuates to its isolation position.
Isolation valves closed to satisfy these requirements may be reopened on an intermittent basis under administrative controls.
l RIVER BEND - UNIT 1 3/4 6-31 Amendment No. 0,47,72,76 l
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.b CONTAINMENT SYSTEMS
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' SURVEILLANCE REQUIREMENTS"(Continued) i
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5 4.6.4.3 ' The " isolation time of.e'ach power operated or ' automatic" valve 'shall be L l'
' determined to be within its limit when tested pursuant-to.Specificationi4.0.5'..
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' RIVER BEND - UNIT 1 3/4 6-31a Amendment No. 9 76 1
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i RIVER BEND - UNIT 1 3/4 6-32 Amendment No. 9 76 7
(Next page is 3/4 6-48)
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i CONTAINMENT SYSTEMS-3/4.6.5 ' SECONDARY CONTAINMENT' SECONDARY CONTAINMENT INTEGRITY - SPERATING LIMITING CONDITION FOR OPERATION
'I 3.6.5.1 SECONDARY CONTAINMENT INTEGRITY - OPERATING shall be maintained.
]
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APPLICABILITY: OPERATIONAL CONDITIONS 1, 2, and 3.
ACTION:
without SECONDARY CONTAINMENT INTEGRITY - OPERATING restore SECONDARY CONTAINMENT INTEGRITY - OPERATING within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months or be in at least NOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following i
24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , j
q SURVEILLANCE REQUIREMENTS i
4.6.5.1 SECONDARY CONTA:NMENT INTEGRITY - OPERATING shall be demonstrated by:
a.
Verifying at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months that the pressures within the l
Shiele Building annulus, the Auxiliary Building and the Fuel Building 1
are less than or equal to 3.0, 0.00, and 0.00 indhes of vacuum water l
gauge, respectively.
l b.
h-ifying at least once per 31 days that:
]
1.
All secondary containment equipment hatch covers are installed.
j 2.
The door in each access to the secondary containment'is. closed, except during normal entry and exit.
j 8
3.
All secondary containment penetrations not capable of being i
closed by OPERABLE secondary containment automatic isolation t
dampers and required to be' closed during accident conditions are closed by valves, blind flanges, or deactivated automatic dampers / valves secured in position, j
i I
RIVER SEND - UNIT 1 3/4 6-48 l
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CONTAINMENT SYSTEMS SECONDARY CONTAINMENT AUTOMATIC ISOLATION DAMPERS LIMITING CONDITION FOR OPERATION 3.6.5.3 - Each secondary containment ventilation system automatic isolation I
damper shall be OPERABLE.
I E ICABILITY: - OPERATIONAL CONDITIONS 1, 2, 3.
- FOR FUEL BUILDING DAMPERS: OPERATIONAL CONDITIONS 1, 2, 3, AND ff.
M9E:
With one or more of the secondary containment ventilation system automatic isolation dampers inoperable, maintain at least one isolation damper OPERABLE in each affected penetration that is open and, within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months , either:
a.
Restore the it. operable damper (s) to OPERABLE status, or t
b.
Isolate each affected penetration by use of at least one deactivated automatic damper secured in the isolation position and declare the-associated system inoperable, if applicable, and perform the assoc-iated ACTION statements for that system, or c.
Isolate each affected penetration by use of at least one closed manual valve or blind flange and declare the associated system inoperable, if applicable, and perform the associated ACTION statements for that system..
i i
Otherwise, in OPERATIONAL CONDITION I, 2 or 3, be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .
Otherwise, in Operational Condition ##, suspend handling of irradiated fuel in the Fuel Building. The provisions of Specification 3.0.3 are not applicable.
SURVEILLANCE RE0VIREMENTS 4.6.5.3 Each secondary containment ventilation system automatic isolation damper shall be demonstrated OPERABLE:
)
a.
Prior to returning the damper to service after maintenance, repair or replacement work is performed on the damper or its associated actuator, control or power circuit, by cycling the damper through at least one complete cycle of full travel and verifying the isolation j
time.
When irradiated fuel is being handled in the Fuel Building.
RIVER BEND - UNIT 1 3/4 6-51 Amendr.ent No. 4h 76 1
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o SURVEILLANCE REQUIREMENTS (Continued)
,1-E 4
.At*leastionce perJ18? months,-d'uring,CO'LO SHUTDOWN'or REFUELING,.by?
Hi 5
verifying that,. on a. secondary containmentiisolationitest signal',-
'j each - secondary -containment ' automatic ' isolation' damper actuates' to ?
'its isolation position.
~
j
_ By verifying the; isolation time to be within.itsclimit' when tested..
-l c.
' pursuant to-Specification 4.0.5.
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i RIVER BEND UNIT l' 3/4 6-52 Amendment No. 9776
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1 Table 3.6.5.3-1 has been deleted.
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j RIVER BEND - UNIT 1 3/4 6-53 Amendment No. 76 (Next page is 3/4 6-55) i
f ELECTRICAL POWER SYSTEMS
?
3/4.8.4 ELECTRICAL E0VIPMENT PROTECTIVE DEVICES' PRIMARY CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES l
l LIMITING CONDITION FOR OPERATION-
+
3.8.4.1 'Each of the primary and backup overcurrent protective devices associated with each primary containment electrical penetration circuit shall be OPERABLE. The scope of these protective devices excludes those circuits for which credible fault currents would not exceed the electrical penetrations' design. ratings.
APPLICABILITY: OPERATIONAL CONDITIONS 1, 2, and 3.
ACTION:
With one or more of the overcurrent protective devices inoperable, declare the l affected system or component inoperable and apply the appropriate ACTION statement for the affected system and:
a.
For 4.16 kV circuit breakers, de-energize the 4.16 kV circuit (s) by tripping the associated redundant circuit breaker (s) within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months and l
verifying, at least once per 7 days thereafter, the redundant circuit breaker to be tripped.
b.
For 480 volt circuit breakers, remove the inoperable circuit breaker (s) from service by racking out the breaker within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months and verifying, at least once per 7 days thereafter, the inoperable breaker (s) to be racked out.
c.
For 480 volt MCC circuit breaker / fuse combination starters, remove the inoperable starter (s) from service by locking the breakers open and i
removing the control power fuse within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months and verifying, at least t
once per 7 days thereafter, the _ inoperable starter (s) circuit breaker to be locked open with the control power fuse removed.
i d.
For 120/140 volt molded case circuit breakers, remove' the inoperable cir-cult breaker (s) from service by tripping both 120/140 volt breakers open and locking the upstream 480. volt MCC breaker _open within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months and verifying, at least once per 7 days thereafter, the 480 volt MCC breaker (s) to be locked open.
Otherwise, be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD l
SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .
j
)
RIVER BEND - UNIT 1 3/4 8-25 Amendment No. 4h76
m,
' ELECTRICAL POWER-SYSTEMS-
SURVEILLANCE REQUIREMENTS l
t t
7 4.8.4'.1 Each of the overcurrent protective devices-shall be demonstrated <
l-t OPERABLE:
a.
' At least once per 18 ' months:
l i
1.
By verifying that' the medium voltage 4.16 kv circuit breakers _.
.are 0PERABLE by selecting, on a rotating basis, at least one of' the four circuit breakers and performing:
a)
A CHANNEL CALIBRATION of the associated protective relays, and t
b)
An integrated system functional test which includes simulated automatic actuation of the system and verifying that each relay and associated circuit breakers and overcurrent control circuits function as designed.
c)
For each circuit breaker found inoperable during these functional tests, an additional' representative sample of at least one of the four circuit breakers of the inoperable type shall also be functionally tested'until no more failures are found or all circuit breakers of that-type have been functionally tested.
2.
By selecting and functionally testing a representative. sample -
of at least 10% of each type of lower voltage circuit breakers.
Circuit breakers selected for functional testing shall be selected on a rotating basis. Testing of these circuit r
breakers shall consist of injecting currents in excess of the breaker's nominal setpoint and measuring the response time of the long time and short time delay elements and the setpoint of the instantaneous element, as appropriate.
The measured data i
shall be compared to'the manufacturer's data to ensure that it is less than or equal to a value specified by the manufacturer.
Circuit breakers found inoperable during functional testing i
.shall be restored to OPERABLE st,-tus prior to resuming-operation. For each circuit breaker found inoperable during i
these functional tests, an additional representative sample of at least 10% of all the circuit breakers of the inoperable type shall also be functionally tested until no more failures are found or all circuit breakers of that type have been functionally tested.
i RIVER BEND - UNIT 1 3/4 8-26 Amendment No.76 i
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0 a-d n
' ELECTRICAL POWER SYSTEMS
]
u SURVEILLANCE REQUIREMENTS (Continued) 3.
By selecting and functionally testing a representative-sample' of at least 10% of each type of motor starter used for pene -
l tration redundant overcurrent protection.. Motor starters selected
~
~for' functional testing shall be selected on a rotating basis.
' Testing of these motor starters shall consist of injecting a.
current with a value equal to the locked rotor current of the associated motor and verifying ~ that the motor starter: operates to interrupt the current within the associated thermal'overloadt time delay band width for that current as specified by the 'manu-facturer.
Motor starters found inoperable during functional testing shall be ~ restored to OPERABLE status prior to resuming operation.
For each motor starter found inoperable during these functional tests, an additional representative sample of at least 10% of all the motor starters of the inoperable type shall:also be functionally tested until no more failures are found or all motor starters of that type have been functionally tested.'
b.
At least once per 60 months by subjecting each circuit breaker to an inspection and preventive maintenance program in accordance with pro -
i cedures' prepared in conjunction with its manufacturer's recommendations.
?
)
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RIVER BEND - UNIT 1 3/4 8-27
\\
g 1
Table 3.8.4.1-1 has been deleted.
RIVER BEND - UNIT 1 3/4 8-28 Amendment No.76
-(Next page is 3/4 8-33)
g~
~
g ELECTRICAL POWER SYSTEMS a
OTHER 6VERCURRENT PROTECTIVE DEVICES i
LIMITING CONDITION FOR OPERATION-l 3.8.4.2 ~ Each primary ov'ercurrent protection devic.e-for the Main control Room :
safety-related lighting and the: primary and secondary RPS Alternate Source of t
LPower;shall be OPERABLE.
APPLICABILITY: At all times.
ACTION:.
With one or more of the overcurrent protective devices? inoperable, remove the l..
- circuit breaker (s) feeding the control room lighting and/or alternate RPS:
'l supply as ap)ropriate from service by opening the breaker (s) within-72 hours.
-and return: tie overcurrent protection devices to OPERABLE status within 7
. days, or verify the appropriate breakers.open at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .*
SURVEILLANCE REOUIREMENTS l
4.8.4.2 The overcurrent protective devices shall be demonstrated OPERABLE-1 at least once per 18 months.by selecting and testing one-half of each type of.
-l circuit breaker on a rottfing basis. Testing of these circuit breakers shall!
j consist of injecting currents-in. excess of the breaker'.s nominal setpoint and measuring the response time of_ the long time and short time delay elements:-
and the setpoint of the instantaneous element, as appropriate. The measured i
data shall be compared to the manufacturer's data to ensure that it is less 1
than or equal to a value specified by the' manufacturer.
q l
4
Except at least once per 31 days if locked, sealed, or otherwise secured in I
the open position.
RIVER BEND - UNIT 1 3/4 8-33 Amendment No. 4h76 I
y.-
n t;
t a
h i
.k Table 3.8.4.2-1 has been deleted.
l t
k RIVER BEND - UNIT 1 3/4 8-34 Amendment No. 76 i
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i P
~ ELECTRICAL POWER SYSTEMS ep REACTOR-PROTECTION SYSTEM ELECTRIC POWER MONITORIWGL iLIMITING' CONDITION FOR OPERATION-J3.8.4.3: Two RPSl electric' power monitoring channels for.each.in-service RPS MG-
)
set or alternate power supply'shall~ be OPERABLE.
sAPPLICABILITY.At all times.
j
^
ACTION: '
j
a. ' With one RPS electric power monitoring channel for an in-service RPS '
.)
MG set or alternate power ' supply inoperable, restore the inoperable
.)
power monitoring channel to OPERABLE status.within-72 hours ort l
remove the associated RPS MG set or alternate _' power supply:from -
service.
i b.
With-both RPS electric power monitori_ng channels for ancin-service l
RPS MG set or alternate power supply inoperable, restore at least~
one electric power monitoring channel to OPERABLE status within 30-minutes or remove the as:;ociated RPS MG set or alternate power j
supply from service.
i SURVEILLANCE REQUIREMENTS l
4.8.4.3 The above specified. RPS electric power monitoring channels shall be :
determined OPERABLE:
'l a.-
By performance of a CHANNEL _ FUNCTIONAL = TEST each time the unit is=in' COLD SHUTDOWN for a period of more than 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ,'unless performed within the' previous six months,' and-
~
.:j b.
At. least once per 18 months *.by demonstrating the OPERABILITY of '
f i
over-voltage, under-voltage and under-frequency protective 1
instrumentation' by performance of a CHANNEL CALIBRATION including ~
simulated automatic actuation of the protective relays, tripping
?
logic and output' circuit breakers and verifying the following l
setpoints.
1.
Over-voltage s 132 VAC,-Bus A and B, i
~
2.
Under-voltage ;t 115 VAC, Bus A and B,- and 3.
Under-frequency 57 Hz, + 2, - 0%, Bus A and B.
l 3
-l 1
4
. May-be extended to the completion of the fifth refueling outage scheduled to begin April 16, 1994..
L
)
RIVER BEND ~- UNIT 1 3/4 8-35 Amendment No. 72 l
i
ELECTRICAL POWER SYSTEMS
'A.C. CIRCUITS INSIDE CONTAINMENT
' LIMITING' CONDITION FOR OPERATION J3.8.4.4Each 480 V and 240/120.V A.C. circuit inside containment for the'
Containment Building HVAC,. Drywell Cooling HVAC, RWCU, Inclined Fuel Transfer Tube, and Reactor Building Main Hoist systems without redundant penetration protection shall be de-energized *.
APPLICABILITY:. OPERATIONAL CONDITIONS 1, 2 and 3.
ACTION:
With any A'.C. circuit energized, trip the associated circuit breaker (s).in the specified location within I hour.
SURVEILLANCE REQUIREMENTS' 4.8.4.4 Each A.C. circuit shall be determined to be de-energized by verifying"
-l at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ** that the associated circuit breakers are.in the tripped condition.
c i
Except during entry into the containment.
Except at least once per 31 days if locked, sealed or otherwise secured in the tripped condition.
RIVER BEND - UNIT 1 3/4 8-36 Amendment No. 76
p.c j
' ADMINISTRATIVE-CONTROLS P
RESPONSIBILITIES (Continued) a c.
Provide written notification within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months to the Senior Vice
. President - RBNG and the Nuclear Review Board of disagreement
[
between the FRC and -the~ Plant Manager; however,. the Plant Manager.
shall have responsibility for resolution of such disagreements pursuant to Specification 6.1.1.
RECORDS 6.5.1.8 The FRC shall maintain written minutes of each~ FRC meeting that, at a minimum, document the results of all FRC activities performed under the:
responsibility provisions of these Technical Specifications.
Copies shall be provided to the Plant Manager and the NRB.
6.5.2 TECHNICAL REVIEW AND CONTROL i
6.5.2.1 Each procedure and program required by Specification 6.8 and other
~
procedures that affect nuclear safety, and changes thereto, is prepared by a qualified individual / organization.
Each such procedure, and changes thereto, shall be' reviewed by an individual / group other than the individual / group that prepared the procedure, or' changes thereto, but who may be from the same organization as the individual / group that prepared the procedure.
Each such r
procedure and program, or changes thereto, shall be approved, prior to implementation, by the Plant Manager, one of the Assistant Plant Managers or the Director - Radiological Programs, or the manager / department head responsible-for the program or the activity described in the procedure, with the exception' of the Emergency Plan and implementing procedures which shall be approved by' the Manager - Administration,' Plant Manager 'and Senior 'Vice President - RBNG.
6.5.2.2 Individuals responsible for reviews performed in accordance with Sec-tion 6.5.2.1 shall be members of River Bend Nuclear Group supervisory staff, L
and the reviews shall be-performed in accordance with administrative procedures.
Each such review shall include a determination of whether or not additional, cross-disciplinary review 1s necessary and a verification that 'the t
. proposed actions do not constitute an unreviewed safety question.
If deemed necessary, such review shall be performed by the appropriate designated. review' personnel.
6.5.2.3 The station security program and implementing procedures shall be a
reviewed at least once per 12 months, and recommended. changes approved in ac-cordance with Specification 6.5.2.1.
l 6.5.2.4 The station emergency plan and implementing procedures and recommended changes shall be approved in accordance with Specification 6.5.2.1.
6.5.2.5 The station fire protection plan and implementing procedures shall-be reviewed at least once per 12 months, and recommended changes approved in accordance with Specification 6.5.2.1.
6.5.2.6 The station Technical Requirements Manual and implementing procedures and recommended changes shall be approved in accordance with' Specification 6.5.2.1.
6.5.2.7 Records documenting each of the activities performed 'under Specifica-tions 6.5.2.1 through 6.5.2.6 shall be maintained.
)
I RIVER BEND - UNIT 1 6-9 Amendment No. 17,52,51,76
ADMINISTRATIVE CONTROLS 6.5.3 NUCLEAR REVIEW BOARD (NRB) a FUNCTIOP 6.5.3.1 The NR8 shall function to provide independent review and audit of designated activities in the areas of:
a.
Nuclear power plant operations, i
b.
Nuclear engineering, c.
. Chemistry'and radiochecaistry,-
d.
Metallurgy, e.
Instrumentation and control, f.
Radiological safety, g.
Mechanical and electrical engineering, h.
Quality assurance practices, 1.
Licensing and regulatory affairs, j.
Training.
The NRB shall report to and advise the Senior Vice President - RBNG on those areas of responsibility in Specifications 6.5.3.7 and 6.5.3.8.
COMPOSITION 6.5.3.2 The NRB shall be composed of at least nine but not more than thirteen individuals who shall possess the necessary expertise to provide the independent review and audit functions identified in Specification 6.5.3.1.
All members shall be qualified to the applicable portions of ANSI /ANS 3.1-1978, Section 4.7, prior to being approved by the Chairperson.
This qualification will be maintained while assigned to NRB activities.
The Senior Vice President-RBNG i
provides nominations for permanent NRB membership to the NRB Chairperson for review and approval.
ALTERNATES 6.5.3.3 All alternate members shall be appointed in writing by the NRB Chairperson and be qualified to the applicable portions of ANSI /ANS 3.1-1978, Section 4.7, prior to being approved by the Chairperson.
This qualification will be maintained while assigned to NRB activities.
CONSULTANTS 6.5.3.4 Consultants shall be utilized as determined by the NRB Chairperson l
to provide expert advice to the NRB.
MEETING FREQUENCY 6.5.3.5 The NRB shall meet at least once per 6 months.
l i
RIVER BEND - UNIT 1 6-10 Amendment No. 27, 61 i
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' ; ADMINISTRATIVE CONTROLS
-1 J
q f: RECORDS (Continued)j d
a..
Minutes.of each NRB meeting lshall be prepared,' approved,'and forwarded to the Senior.Vice President.- RBNG within 14 days following each r
meeting.-
~
b.'
Reports of raviews encompassed by Specification.6.5f3.7 shall be prepared, gproved, and forwarded to the Senior Vice President ' RBNG l
within 14 dqys following completion of the review..
j t
Audit reports encompassed by Specification 6.5.3.8 'sha11 be forwarded :.
E c..
to the Senier. Vice President, RBNG, and to'.the~ management positions-
'1 responsible for the areas audited, within 30 days after completion of the audit by the auditing organization.
~
~.
6. 6 REPORTABLE EVENT ACTION I
6.6.1 The following actions shall be taken for REPORTABLE EVENTS-i
^t
~
-I The Commission shal1 ~ be notified and a report submitted pursuant to l
a.
the requirements of 10 CFR 50.73 and i
b.
Each REPORTABLE EVENT shall be reviewed by the FRC and the results' of this review shall be submitted to the NRB and the Plant Manager.
i
6. 7 SAFETY LIMIT VIOLATION L.:
6.7.1 The following actions'shall be taken in the event a Safety Limit is
]
violated:
(
a.
The.NRC Operations Center shall,be notified by telephone as soon as-
.i possible and in all cases within'l hour.
The Senior Vice President '-
I RBNG and the NRB chairman (or' personnel acting for their function) shall be notified within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .
b.
A Safety Limit Violation Report shall be prepared. The report shall-l be reviewed by the FRC.
This report shall describe (1) applicable circumstances preceding the violation, (2) effects of the violation.
upon unit camponents, systems, or structures, and (3) corrective action.
taken to prevent recurrence.
c.
The Safety Limit Violation Report shall be-submitted to the Commission, l
the NRB, and the Senior Vice President - RBNG within 14 days of the
'I violation.
j d.
Critical operation of the unit shall not be resumed until authorized-by the Commission.
6. 8 PROCEDURES AND PNGRAMS j
l 6.8.1 Written procedures shall be established, implemented, and maintained l
covering the activities referenced below:
j f
RIVER BEND - UNIT 1 6-13 I
1
/
r ADMINISTRATIVE CONTROLS'
' PROCEDURES AND PROGRAMS (Continued) a.
' The applicable. procedures recommended in Appendix A of Regulatory i
Guide 1.33, Revision 2, February 1978.
b.
.The applicable procedures required;to implement the requirements of
' NUREG-0737 and supplements thereto.
c.
Refueling operations.
d.
Surveillance and test activities of safety-related equipment.
e.
Security Plan implementation.
f.
Emergency Plan implementation.
g.
Fire Protection Program implementation.
h.
Process Control Program implementation.
i.
Offsite Dose Calculation Manual implementation.
f.
Quality Assurance Program for effluent and environmental monitoring.
l k.
Technical Requirements Manual implementation.
6.8.2 Each procedure of Specification 6.8.1, and changes thereto, shall be reviewed and approved in accordance with Specification 6.5.2.1.
6.8.3 Temporary c'anges to procedures of Specification 6.8.1 may be made pro-vided:
a.
The intent of the original procedure is not altered; b.
The change is approved by two members of the plant management staff, at least one of whom holds a Senior Operator license on the unit affected; and c.
The change is documented, reviewed by the FRC as required by Specification 6.5.1.6, and approved in accordance with Specification 6.5.2.1 within 14 days of implementation.
6.8.4 The following programs shall be established, implemented, and maintained:
a.
Primary Coolant Sources Outside Containment A program to reduce leakage, from those portions of systems outside containment that could contain highly radioactive fluids during 'a serious transient or accident, to as low as practicable levels. The systems include the HPCS, LPCS, RHR, RCIC, process sampling, and standby gas treatment systems.
The program shall include the following:
1.
Preventive maintenance and periodic visual inspection requirements, and RIVER BEND - UNIT 1 6-14 Amendment No. 76
.

ML20081B779

Text

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