Text

Amend 67 to License NPF-58,revising TS Sections 3/4.3, Intrumentation, 3/4.4.2, Safety/Relief Valves, & Associated Bases to Increase STI & Allowable out-of-svc Times
	ML20078L916
Person / Time
Site:	Perry
Issue date:	11/22/1994
From:	Hopkins J; Office of Nuclear Reactor Regulation
To:	;
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UNITED STATES

~

E NUCLEAR REGULATORY COMMISSION

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j WASHINGTON, D.C. 20066 4 001 gn..../

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THE CLEVELAND ELECTRIC ILLUMINATING COMPANY. ET AL.

DOCKET NO. 50-440 PERRY NUCLEAR POWER PLANT. UNIT NO. 1 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No. 67 License No. NPF-58 I

1 1.

W Nuclear Regulatory Co mission (the Commission) has found that:

A.

The application for amendment by The Cleveland Electric Illuminating Company, Centerior Service Company, Duquesne Light Company, Ohio Edison Company, Pennsylvania Power Company, and Toledo Edison Company (the licensees) dated June 29, 1992, and supplemented on February 22, 1994, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's rules l

and regulations set forth in 10 CFR Chapter I-

- i B.

The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission C.

There is reasonable assurance (i) that the activities authorized by

(

this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commission's regulations; J

D.

The issuance of this amendment will not be inimical to the common i

defense and security or to the health and safety of the public; and i

E.

The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied.

2.

Accordingly, the license is amended by changes to the Technical Specifi-l

. cations as indicated in the attachment to this license amendment, and i

paragraph 2.C.(2) of Facility Operating License No. NPF-58 is hereby i

amended to read as follows:

i i

9412010218 941122 PDR ADOCK 05000440 i

P PDR j

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. (2) Technical Specifications The Technical Specifications contained in Appendix A and the Environmental Protection Plan contained in Appendix B, as revised through Amendment No. 67 are hereby incorporated into this license.

The Cleveland Electric Illuminating Company shall operate the facility in accordance with the Technical Specificatior.s and the Environmental Protection Plan.

3.

This license amendment is effective as of its date of issuance and shall be implemented not later than 180 days after issuance.

FOR THE NUCLEAR REGULATORY COMMISSION Jon B. Hopkins, Sr. Project Manager Project Directorate III-3

(

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

Attachment:

Changes to the Technical Specifications Date of issuance:

November 22, 1994 f

4 i

a

ATTACHMENT TO LICENSE AMENDMENT NO. 67 FACILITY OPERATING LICENSE NO. NPF-58

' DOCKET NO. 50-440 Replace the following pages of the Appendix "A" Technical Specifications with j

the attached pages. The revised pages are identified by Amendment number and contains vertical lines indicating the area of change.

Remove Insert I

xviii xviii xix xix l

3/4 3-1 3/4 3-1 j

3/4 3-5 3/4 3-5 i

3/4 3-7 3/4 3-7 3/3 3-8 3/4 3-8 3/4 3-8a 3/4 3-9' 3/4 3-9 l

3/4 3-11 3/4 3-11 i

3/4 3-16 3/4 3-16 3/4 3-23 3/4 3-23 i

3/4 3-24 3/4 3-24 3/4 3-25 3/4 3-25 3/4 3-26 3/4 3-26 3/4 3-28 3/4 3-28 i

3/4 3-29 3/4 3-29 3/4 3-30 3/4 3-30 l

3/4 3-31 3/4 3-31 l

3/4 3-31a 3/4 3-37 3/4 3-37 3/4 3-38 3/4 3-38 1

3/4 3-39 3/4 3-39 3/4 3-40 3/4 3-40 3/4 3-41 3/4 3-41 3/4 3-43 3/4 3-43 3/4 3-44 3/4 3-44 3/4 3-46 3/4 3-46 4

3/4 3-49 3/4 3-49 i

3/4 3-51 3/4 3-51 3/4 3-52 3/4 3-52 3/4 3-54 3/4 3-54 i

3/4 3-56 3/4 3-56 l

3/4 3-57 3/4 3-57 t

3/4 3-59 3/4 3-59 3/4 3-60 3/4 3-60 l

3/4 3-98 3/4 3-98 3/4 3-99 3/4 3-99 3/4 3-100 3/4 3-100 t

3/4 3-100a 3/4 3-102 3/4 3-102 c

,,r n...

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.. Attachment to License Amendment No. 67 (Continued) 3/4 4-7 3/4 4-7 6

3/4 4-8 3/4 4-8 i

B 3/4 3-1 B 3/4 3-1 B.3/4 3-2 B 3/4 3-2 B 3/4 3-2a B 3/4 3-3 B 3/4 3-3 l

B 3/4 3-3a B 3/4 3-4 8 3/4 3-4 B 3/4 3-4a B 3/4 3-4a i

B 3/4 3-4b 8 3/4 3-7 B 3/4 3-7 i

B 3/4 4-3 8 3/4 4-3 B 3/4 4-3a i

r i

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Y f

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BASES SECTION PEGE 3/4.0 APPLICABILITY B 3/4 0-1 3/4.1 REACTIVITY CONTROL SYSTEM 3/4.1.1 SHUTDOWN MARGIN B 3/4 1-1 3/4.1.2 REACTIVITY ANOMALIES...................

B 3/4 1-1 3/4.1.3 CONTROL RODS.......................

B 3/4 1-2 3/4.1.4 CONTROL R0D PROGRAM CONTROLS...............

B 3/4 1-3 3/4.1.5 STANDBY LIQUID CONTROL SYSTEM B 3/4 1-4 3/4.2 POWER DISTRIBUTION LIMITS 3/4.2.1 AVERAGE PLANAR LINEAR HEAT GENERATION RATE........

B 3/4 2-1 3/4.2.2 HINIMUM CRITICAL POWER RATIO...............

B 3/4 2-4 3/4.2.3 LINEAR HEAT GENERATION RATIO...............

B 3/4 2-5 Bases Figure B 3/4 2.2-1 Power to Flow Operating Map B 3/4 2-6 3 /4.3 INSTRUMENTATION 3/4.3.1 REACTOR PROTECTION SYSTEM INSTRUMENTATION B 3/4 3-1 3/4.3.2 ISOLATION ACTUATION INSTRUMENTATION B 3/4 3-2 3/4.3.3 EMERGENCY CORE COOLING SYSTEM ACTUATION INSTRUMENTATION B 3/4 3-2a l

3/4.3.4 RECIRCULATION PUMP TRIP ACTUATION INSTRUMENTATION B 3/4 3-3 3/4.3.5 REACTOR CORE ISOLATION COOLING SYSTEM ACTUATION INSTRUMENTATION B 3/4 3-4 3/4.3.6 CONTROL ROD BLOCK INSTRUMENTATION B 3/4 3-4 PERRY - UNIT 1 xviii Amendment No.-GO, 67

BASES SECTION Pfjf INSTRUMENTATION (Continued) 3/4.3.7 MONITORING INSTRUMENTATION Radiation Monitoring Instrumentation B 3/4 3-4a Seismic Monitoring Instrumentation B 3/4 3-4b Meteorological Monitoring Instrumentation B 3/4 3-4b Remote Shutdown System Instrumentation and Controls B 3/4 3-5 l

Accident Monitoring Instrumentation B 3/4 3-5 Source Range Monitors B 3/4 3-5 Traversing In-Core Probe System B 3/4 3-5 Loose-Part Detection System B 3/4 3-6 Radioactive Liquid Effluent Monitoring Instrumentation B 3/4 3-6 Radioactive Gaseous Effluent Monitoring Instrumentation B 3/4 3-6 3/4 3.8 TURBINE OVERSPEED PROTECTION SYSTEM B 3/4 3-6 1

3/4.3.9 PLANT SYSTEMS ACTUATION INSTRUMENTATION B 3/4 3-6 Bases Figure B 3/4 3-1 Reactor Vessel Water Level B 3/4 3-8 3/4,4 REACTOR COOLANT SYSTEM 3/4.4.1 RECIRCULATION SYSTEM B 3/4 4-1 3/4.4.2 SAFETY / RELIEF VALVES B 3/4 4-2

{

3/4.4.3 REACTOR COOLANT SYSTEM LEAKAGE Leakage Detection Systems B 3/4 4-3 Operational Leakage B 3/4 4-3a l

j 3/4.4.4 CHEMISTRY B 3/4 4-4 PERRY - UNIT 1 xix Amendment No. 67

3/4.3 INSTRUMENTATION l

3/4.3.1 REACTOR PROTECTION SYSTEM INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.1 As a minimum, the reactor protection system instrumentation channels shown in Table 3.3.1-1 shall be OPERABLE with the REACTOR PROTECTION SYSTEM RESPONSE TIME as shown in Table 3.3.1-2.

APPLICABILITY:

As shown in Table 3.3.1-1.

ACTION:

With one channel required by Table 3.3.1-1 inoperable in one or more a.

Functional Units thetrippedcondition*within12 hours. place the inoperable channel and/or that trip system b.

With two or more channels required by Table 3.3.1-1 inoperable in one or more Functional Units; 1.

Within one hour, verify sufficient channels remain OPERABLE or are in the tripped condition

to maintain trip capability in the Functional Unit, and 2.

Within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , place the inoperable channel (s) in one trip system and/or that trip system ** in the tripped condition,* and 3.

Within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , restore the inoperable channels in the other trip system to an OPERABLE status or place them in the tripped condition *.

Otherwise, take the ACTION required by Table 3.3.1-1 for the Functional Unit.

SURVEILLANCE RE0VIREMENTS 4.3.1.1 Each reactor protection system 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 4.3.1.1-1.

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

4.3.1.3 The REACTOR PROTECTION SYSTEM RESPONSE TIME of each reactor trip functional unit shown in Table 3.3.1-2 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 reactor trip system.

4.3.1.4 The provisions of Specification 4.0.4 are not applicable to the CHANNEL FUNCTIONAL TEST and CHANNEL CALIBRATION surveillances for the Intermediate Range Monitors for entry into their applicable OPERATIONAL CONDITIONS (as shown in Table 4.3.1.1-1) from OPERATIONAL CONDITION 1, provided the surveil ances are performed within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after such entry.

An inoperable channel or trip system need not be placed in the tripped 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 3.3.1-1 for the Functional Unit 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 ACTION can be applied to either trip system.

PERRY - UNIT I 3/4 3-1 Amendment No. -4h -f4 67

l TABLE 3.3.1-1 (Continued)

REACTOR PROTECTION SYSTEM INSTRUMENTATION TABLE NOTATIONS (a)

When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated ACTIONS may be delayed for up t:, 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Functional Unit maintains RPS trip c:.pability.

(b)

Unless adequate shutdown margin has been demonstrated per Specification 3.1.1 and the "one-rod-out" Refuel position interlock has been demonstrated OPERABLE per Specification 3.9.1, the shorting links shall be removed from the RPS circuitry prior to and during the time any control rod is withdrawn.*

(c)

An APRM channel is inoperable if there are less than 2 LPRM inputs per level or less than 14 LPRM inputs to an APRM channel.

(d)

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

(e)

This function shall be automatically bypassed when the reactor mode switch is not in the Run position.

(f)

This function is not required to be OPERABLE when DRYWELL INTEGRITY is not required.

(g)

With any control rod withdrawn. Not applicable to control rods removed per Specification 3.9.10.1 or 3.9.10.2.

(h)

This function is automatically bypassed when turbine first stage pressure is less than the value of tarbine first stage pressure corresponding to 40%** of RATED THERMAL POWER.

Not required for control rods removed per Specification 3.9.10.1 or 3.9.10.2.

- The Turbine First Stage Pressure Bypass Setpoints and corresponding Allowable Values are adjusted based on Feedwater temperatures (see 3/4.2.2 for definition of AT). The Setpoints and Allowable Values for various ATs are as follows:

T('F)

Setooint (osio)

Allowable Value (osio) 0-T 5 212 1 218 r

0 < AT s 50 s 190

$ 196 50 < AT s 100 s 168 s 174 100 < AT s 170

$ 146 s 152 PERRY - UNIT 1 3/4 3-5 Amendment No. -Gh 67

g TABLE 4.3.1.1-1

o f

REACTOR PROTECTION SYSTEM INSTRUMENTATION SURVEILLANCE REQUIREMENTS E

CHANNEL OPERATIONAL Z

CHANNEL FUNCTIONAL CHANNEL CONDITIONS IN WHICH FUNCTIONAL UNIT

_ CilECK TEST CALIBRATION (a) SURVEILLANCE REQUIRED

1. ' Intermediate Range Monitors:

a.

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

W R

2 S

W R

3,4,5 b.

Inoperative NA W

NA 2,3,4,5 2.

Average Power Range Monitor:(f) a.

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

W SA 2

Setdown S

W SA 3, 5 b.

Flow Biased Simulated e.

Themal Power - High S,D(h)

Q W '(*), SA(*), R(')

1 id w

c.

Neutron Flux - High S

Q Vd), SA 1

d.

Inoperative NA Q

NA 1, 2, 3, 5 3.

Reactor Vessel Steam Dome Pressure - High S

Q R(')

1, 2(D 4.

Reactor Vessel Water Level -

Low, Level 3 S

Q R(')

1, 2 E

a 5.

Reactor Vessel Water Level -

y High, level 8 S

Q R(

I k

6.

Main Steam Line Isolation g

Valve - Closure NA Q

R 1

p 7.

Deleted e

g TABLE 4.3.1.1-1 (Continued)

o 7

REACTOR PROTECTION SYSTEM INSTRUMENTATION SURVEILLANCE REOUIREMENTS E

CHANNEL OPERATIONAL Z

CHANNEL FUNCTIONAL CHANNEL CONDITIONS IN WHICH FUNCTIONAL UNIT CHECK -

TEST CALIBRATION SURVEILLANCE REQUIRED 8.

Drywell Pressure - High S

Q R(

1, 2"'

l 9.

Scram Discharge Volume Water Level - High a.

Level Transmitter S

Q R(

1, 2, 5("'

b.

Float Switches NA Q

R 1, 2, 5(*)

10. Turbine Stop Valve - Closure NA Q

-R 1

l

11. Turbine Control Valve Fast Closure, Valve Trip System 011 Pressure - Low NA Q

R 1

l

12. Reactor Mode Switch w

!=

Shutdown Position NA R

NA 1,2,3,4,5

13. Manual Scram NA W

NA 1,2,3,4,5 l

(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 decades during each startup after entering OPERATIONAL CONDITION 2 and the IRM and APRM channels shall be determined to overlap for at least 1/2 decades during each controlled shutdown, if not performed within the previous 7 days.

b"g (c) Deleted E.

i!F 9

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i TABLE 4.3.1.1-1 (Continued) m 7

' REACTOR PROTECTION SYSTEM INSTRUMENTATION SURVEILLANCE REQUIREMENTS sZ (d) This calibration shall consist of the adjustment of the APRM channel to conform to the power values calculated by a heat balance during OPERATIONAL CONDITION 1 when THERMAL POWER 2 25% of RATED THERMAL POWER. Adjust the APRM channel if the absolute difference is greater than 2% of RATED THERMAL POWER. The provisions of Specification 4.0.4 are not applicable provided the surveillance is performed within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reaching 25% of RATED THERMAL POWER. To functionally implement this protective function during entry into single loop operation, APRM chaenel gain adjustments.may be made in lieu of adjusting the APRM Flow Biased Simulated Thermal Power-High Tr!o Setpoint and Allowable Value equations for a period not to exceed 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , provided the criteria in Note 5 to Table 2.2.1-1 are met. Any APRM channel gain adjustments made in compliance with Specifications 2.2.1 aed 3.3.1 shall not be included in determining the absolute difference.

(e) This calibration shall consist of the adjustaent of the APRM flow biased channel to conform to a calibrated w1 flow signal.

(f) The LPRMs shall be calibrated at least once per 1000 MWD /T using the TIP system.

(g) Calibrate trip unit setpoint at least once per 92 days.

l (h) Verify measured core flow (total core flow) to be greater than or equal to established core flow at the existing loop flow (APRM % flow).

(i) This calibration shall consist of verifying that the simulated thermal power time constant is within the limits specified in the COLR.

E h

(j)

This function-is not required to be OPERABLE when the reactor pressure vessel head is removed per

=

Specification 3.10.1.

A (k) With any control rod withdrawn. Not applicable to control rods removed per Specification 3.9.10.1 or g

3.9.10.2.

(1) This function is not required to be OPERABLE when Drywell Integrity is not required.

l (m) The CHANNEL CAllBRATION shall exclude the flow reference transmitters, these transmitters shall be aP calibrated at least once per 18 months.

h.

e L

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INSTRUMENTATION i

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 and with ISOLATION SYSTEM RESPONSE TIME as shown in Table 3.3.2-3.

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 one channel required by Table 3.3.2-1 inoperable in one or more Trip Functions, place the inoperable channel and/or that trip system in the tripped condition

within:

1.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for Trip Functions common to RPS instrumentation, and 2.

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months for Trip Functions not common to RPS instrumentation.

c.

With two or more channels required by Table 3.3.2-1 inoperable in one or more Trip Functions; 1.

Within one hour, verify for automatic Trip Functions that sufficient channels remain OPERABLE or are in the tripped condition

to maintain isolation capability for the Trip Function, and 2.

Within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for Trip Functions common to RPS instrumentation, and within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months for Trip Functions not common to RPS instrumentation, place the inoperable channel (s) in the tripped condition *.

Otherwise, take the ACTION required by Table 3.3.2-1 for the Trip Function.

An inoperable channel or trip system need not be placed in the tripped 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 the Trip Function shall be taken.

I l

i PERRY - UNIT 1 3/4 3-9 Amendment No. -66, 67

a g

1ABLE 3.3.2-1 ISOLATION ACTUATION INSTRUMENTATION t-MINIMUM OPERABLE APPLICABLE 5

CHANNELS PER OPERATIONAL

[

IRIP FUNCTIQti TRIP FUNCT10N"3 CONDITIONS ACTION 1.

PRIMARY CONTAINMENT ISOLATION a.

Reactor Vessel Water Level - Low, level 2 (1) Division 1 & 2 2

1, 2, 3 and #

20 (2) Division 3 4'd3 1, 2, 3 and i 28 b.

Drywell Pressure - High (1) Division 1 & 2 2

1, 2, 3 20 (2) Division 3 4(d' 1, 2, 3 28 c.

Containment and Drywell Purge Exhaust Plenum Radiation - High 2(b' I, 2, 3 and

21 m;

d.

Reactor Vessel Water Level - Low, level 1 2

1, 2, 3 and i 20 e.

Manual Initiation

[

(1) Division I & 2 2"'

1, 2, 3 and

22 (2) Division 3 1")

1, 2, 3 and

28 2.

MAIN STEAM ISOLATION a.

Reactor Vessel Water Level - Low, Level 1 2

1,2,3 20 b.

Main Steam Line Radiation - High 2"'

29 c.

Main Steam Line Pressure - Low 2

1 24 g

d.

Main Steam Line Flow - High 2/line 1, 2, 3 23 g

e.

Condenser Vacuum - Low 2

1,-2**, 3**

23 g

f.

Main Steam Line Tunnel g

Temperature - High 2

1, 2, 3 23 g.

Main Steam Line Tunnel y

A Temperature - High 2

1, 2, 3 23 h.

Turbine Building Main Steam g

Line Temperature - High 2-1, 2, 3 23 1.

Manual Initiation 2

1,2,3 22

.h

f i

i I

t TABLE 3.3.2-1 (Continued)

ISOLATION ACTUATION INSTRUMENTATION ACTION NOTES (Continued)

(a) When a channel 1: placed in an inoperable status solely for performance of required Surveillances, entry into associated ACTIONS may be delayed as follows:

(a) for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Trip Functions 1.e and 5.m; and (b) for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Trip Functions other than 1.e and 5.m provided the associated Trip Function maintains isolation capability.

(b) Containment and Drywell Purge System inboard and outboard isolation valves each use a separate two out of two isolation logic.

(c) There is only one (1) RCIC manual initiation channel for RCIC system containment isolation valves.

(d) Division 3 has only one trip system consisting of four channels logically combined in a one-out-of-two-twice configuration which only closes the HPCS Suppression Pool Test Return Valve (IE22-F023).

(e) Division 3 Hanual Initiation consists of a single channel in a single trip system.

(f) This Trip Function no longer isolates the Main Steam Lines.

The only isolation is of the mechanical vacuum pump lines (valves IN62-F130A l

and B), using a single trip system consisting of two channels configured in a one-out-of-two logic.

F i

PERRY - UNIT 1 3/4 3-16 Amendment No. 44,4ML,4WL, 67 i

i 1

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TABLE 4.3.2.1-1

!8 ISOLATION ACTUATION INSTRUMENTATION SURVEILLANCE REQUIREMENTS I

EE CHANNEL OPERATIONAL El CHANNEL FUNCTIONAL CHANNEL CONDITIONS IN WHICH TRIP FUNCTION CHECK TEST CALIBRATION SURVEILLANCE REQUIRED 1.

PRIMARY CONTAINNENT ISOLATION a.

Reactor Vessel Water Level -

Low, level 2 S

Q R"')

1, 2, 3 and #

b.

Drywell Pressure - High ##

S Q

R"')

1, 2, 3 c.

Containment and Drywell Purge Exhaust Plenum Radiation -

High S

Q R

1, 2, 3 and *

-l d.

Reactor Vessel Water Level -

Low, Level 1 S

Q Rcb>

1, 2, 3 and #

l e.

Manual Initiation NA R

NA 1, 2, 3 and

dd 2.

MAIN STEAM LINE ISOLATION a.

Reactor Vessel Water Level -

if Low, level 1 S

Q R(63 1, 2, 3 l

0; b.

Main Steam Line Radiation -

High ##

S Q

R l

c.

Main Steam Line Pressure -

Low S

Q R(b)

I

d. Main Steam Line Flow - High S

Q Rch) 1, 2, 3 e.

Condenser Vacuum - Low S

Q R""

1, 2**, 3**

f. Main Steam Line Tunnel Temperature - High S

Q R

1, 2, 3 l

g.

Main Steam Line Tunnel jr A Temperature - High S

Q R

1, 2, 3 l

h.

Turbine Building Main Steam gt Line Temperature - High S

Q R

1, 2, 3 l

1. Manual Initiation NA R

NA 1, 2, 3 I

m.

m-

.m

-a w-

A E

l E

TABLE 4.3.2.1-1 (Continued)

Z ISOLATION ACTUATION INSTRUMENTATION SURVEILLANCE REQUIREMENTS CHANNEL OPERATIONAL CHANNEL FUNCTIONAL CHANNEL CONDITIONS IN WHICH TRIP FUNCTION CHECK TEST CALIBRATION SURVEILLANCE REOUIRED 3.

SECONDARY CONTAINMENT ISOLATION a.

Reactor Vessel Water Level - Low, level 2 S

Q R

1, 2, 3 and'f b.

Drywell Pressure - High ##

S Q

R*)

1, 2, 3 c.

Manual Initiation NA-R NA 1, 2, 3 and

4.
REACTOR WATER CLEANUP SYSTEM ISOLATION
a. A Flow - High S
Q R
1, 2, 3 w
- b. A Flow Timer NA Q
R 1, 2, 3 w
c.
Equipment Area Temperature -
A High S
Q R
1, 2, 3 d.
Equipment Area Ventilation A Temperature - High S
Q R
1, 2, 3 e.
Reactor Vessel Water Level - Low, Level 2 S
Q R(6) 1, 2, 3 f.
Main Steam Line Tunnel Ambient Temperature - High 5
Q R
1, 2, 3 g.
Main Steam Line Tunnel A Temperature - High S
Q(*)
R 1, 2, 3 g
h. SLCS Initiation NA Q
NA 1, 2, 3 g
1. Manual Initiation NA R
NA 1, 2, 3 a.
y TABLE 4.3.2.1-1 (Continued) m 7
ISOLATION ACTUATION INSTRUNENTATION SURVEILLANCE REOUIREMENTS E
CHANNEL OPERATIONAL Z
CHANNEL FUNCTIONAL CHANNEL CONDITIONS IN WHICH TRIP FUNCTION CHECK TEST CALIBRATION
. SURVEILLANCE REQUIRED' 5.
REACTOR CORE ISOLATION COOLING SYSTEM ISOLATION a.
RCIC Steam Line Flow - High S
Q R*'
1, 2, 3 b.
RCIC Steam Supply Pressure -
Low S
Q R*'
1, 2, 3 -
c.
RCIC Turbine Exhaust Diaphragm Pressure - High S
Q R*'
1, 2, 3 d.
RCIC Equipment Room Ambient Temperature - High S
Q R
1,2,3 e.
Deleted f.
Main Steam Line Tunnel Ambient g
Temperature - High S
Q R
1, 2, 3 g.
Main Steam Line Tunnel y
A Temperature - High S
-Q R
1, 2, 3 h.
Main Steam Line Tunnel m
Temperature Timer NA Q
R' 1, 2, 3 1.
RHR Equipment Room Ambient Temperature - High S
Q R
1, 2, 3 j.
RHR Equipment Room A Temperature - High S
Q R
1, 2, 3 k.
RCIC Steam Line Flow l
High Timer NA Q
R 1, 2, 3 l
1.
Drywell Pressure - High S
Q Rcb>
1, 2, 3 I
g u.
Manual Initiation NA R
NA 1, 2, 3 3
F
3 TABLE 4.3.2.1-1 (Continued)-
=
7 ISOLATION ACTUATION INSTRUMENTATION SURVEILLANCE REQUIREMENTS E
CHANNEL OPERATIONAL M
CHANNEL FUNCTIONAL CHANNEL CONDITIONS IN WHICH TRIP FUNCTION CHECK TEST CALIBRATION SURVEILLANCE REQUIRED 6.
RHR SYSTEM ISOLATION a.
RHR Equipment Area Ambient Temperature - High S
Q R
1, 2, 3 b.
RHR Equipment Area A Temperature - High S
Q R
1, 2, 3 c.
RHR/RCIC Steam Line Flow - High 5
Q R*'
I, 2, 3 d.
Reactor Vessel Water level -
g Low, Level 3 ff S
Q SR) 1, 2, 3 Y
e.
Reactor Vessel (RHR Cut-in M
Permissive) Pressure - High S
Q R*'
1, 2, 3 f.
Drywell Pressura - High ##
S Q
R*)
1, 2, 3 g.
Nanual Initiation NA R
NA 1, 2, 3
When handling irradiated fuel in the primary containment and during CORE ALTERATIONS and operations with a potential for draining the reactor vessel.
When any turbine stop valve is greater than 90% 7 pen and/or the key locked bypass switch is k
in the normal position.
R
OPERATIONAL CONDITION 1 or 2 when the mechanical vacuum pump lines are not isolated.
R f During CORE ALTERATION and operations with a potential for draining the reactor. vessel.
5 (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.
2 P
f These Trip Functions (Ib, 2b, 3b, 6d, and 6f) utilize instruments which are commen to RPS instrumentation.
M l
~
-, ~.
A
oQ R
TABLE 3.3.3-1
4 EMERGENCY CORE COOLING SYSTEM ACTUATION INSTRUMENTATION MINIMUM OPERABLE APPLICABLE CHANNELS PER OPERATIONAL TRIP FUNCTION TRIP FUNCTION (*)
CONDITIONS ACTION A.
DIVISION 1 TRIP SYSTEM 1.
RHR-A (LPCI MODE) AND LPCS SYSTEM a.
Reactor Vessel Water Level - Low, level 1 2(b) 1,2,3,4*,5*
30 b.
Drywell Pressure-High 2 "')
1, 2, 3 30 LPCS Pump Discharge Flow - Low (Bypass) 1 1, 2, 3, 4*, 5*
39 c.
d.
Reactor Vessel Pressure - Low (LPCS Injection 1
1, 2, 3 31 2d Valve Permissive) 4*, 5*
32 e.
Reactor Vessel Pressure - Low (LPCI Injection 1
1, 2, 3 31 y>
Valve Permissive) 4*, 5*
32 g;
f.
LPCI Pump A Start Time Delay Relay 1
1, 2, 3, 4*, 5*
31 g.
LPCI Pump A Discharge Flow - Low (Bypass) 1 1, 2, 3,'4*, 5*
39 h.
Manual Initiation 1
1, 2, 3, 4*, 5*
33 2.
AUTOMATIC DEPRESSURIZATION SYSTEM TRIP SYSTEM "A"#
a.
Reactor Vessel Water Level - Low, level 1 2"')
1, 2, 3 30 b.
Manual Inhibit 1
1,2,3 31 c.
ADS Timer 1
1,2,3 31 gr d.
Reactor Vessel Water Level - Low, level 3 (Permissive) 1 1, 2, 3 30 l
g e.
LPCS Pump Discharge Pressure - High (Permissive) 2 1, 2, 3 31 gt f.
LPCI Pump A Discharge Pressure - High (Permissive) 2 1, 2, 3 31 g
g.
Manual Initiation 2
1, 2, 3 33
.E
E TABLE 3.3.3-1 (Continued)
E EMERGENCY CORE COOLING SYSTEM ACTUATION INSTRUMENTATION i
C 2
MINIMUM OPERABLE APPLICABLE CHANNELS PER OPERATIONAL TRIP FUNCTION TRIP FUNCTION (*)
CONDITIONS ACTION B.
DIVISION 2 TRIP SYSTEM I.
RHR B AND C (LPCI MODE) a.
Reactor Vessel Water Level - Low, level 1 2*)
1, 2, 3, 4*, 5*
30 b.
Drywell Pressure - High 2*'
1, 2, 3 30 c.
Reactor Vessel Pressure - Low (LPCI Injection 1
1, 2, 3 31 Valve Permissive) 4*,
5*
32 d.
LPCI Pump B Start Time Delay Relay 1
1, 2, 3, 4*, 5*
31 e.
LPCI Pump Discharge Flow - Low (Bypass) 1/ pump 1, 2, 3, 4*, 5*
39 f.
Manual Initiation 1
1, 2, 3, 4*, 5*
33 2.
AUTOMATIC DEPRESSURIZATION SYSTEM TRIP SYSTEM "B"#
w A
a.
Reactor Vessel Water Level - Low, Level 1 2 *'
1, 2, 3 30 b.
Manual Inhibit 1
1, 2, 3 31 c.
ADS Timer 1
1, 2, 3 31 d.
Reactor Vessel Water Level - Low, Level 3 (Permissive) 1 1, 2, 3 30 l
LPCI Pump B and C Discharge Pressure - High (Permissive) 2 1, 2, 3 31 e.
f.
Manual Initiation 2
1,2,3 33 N
a a.
a F
e
TABLE 3.3.3-1-(Continued)
EMERGENCY CORE COOLING SYSTEM ACTUATION INSTRUMENTATION i.
MINIMUM OPERABLE APPLICABLE c
CHANNELS PER OPERATIONAL TRIP FUNCTION TRIP FUNCTION (a)
CONDITIONS
-ACTION C.
DIVISION 3 TRIP SYSTEM 1.
HPCS SYSTEM a.
Reactor Vessel Water Level - Low, level 2 4(b' L L 3, 4*, 5*
34 b.
Drywell Pressure - High##
4(63 1, 2, 3 34 c.
Reactor Vessel Water Level - High, level 8 4")
1, 2, 3, 4*, 5*-
33 l
d.
Condensate Storage Tank Level - Low 2(d' 1, 2, 3, 4*, 5*
35 e.
Suppression Pool % ter Level - High 2(d) 1, 2, 3, 4*, 5*
35 f.
HPCS Pump Discharge Pressure - High (Bypass) 1 1, 2, 3, 4*, 5*
40 g.
HPCS System Flow Rate - Low (Bypass) 1 1, 2, 3, 4*, 5*
40 h.
Manual Initiation ##
1 1, 2, 3, 4*, 5*
33 MINIMUM APPLICABLE TOTAL NO. CHANNELS OPERABLE OPERATIONAL w
4, D.
LOSS OF POWER OF CHANNELS TO TRIP CHANNELS CONDITIONS
' ACTION' o
1.
4.16 kV Emergency Bus Undervoltagefff 2/ bus 2/ bus 2/ bus 1, 2, 3, 4**, 5**
37 (Loss of Voltage) 2.
4.16 kV Emergency Bus Undervoltage###
2/ bus 2/ bus 2/ bus 1,2,3,4",5" 38 (Degraded Voltage)
(a) When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated ACTIONS may be delayed as follows:
(a) for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Trip Functions C.I.f, C.I.g and C.I.h; and (b) for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Trip Functions other than C.l.f, C.I.g, and C.I.h provided the associated Trip Function maintains ECCS initiation capability.
k (b) Also actuates the associated division diesel generator.
R (c) Provides signal to close HPCS pump' injection valve only.
2 (d) Provides signal to HPCS pump suction valves only.
5
When the system is required to be OPERABLE per Specification 3.5.2 or 3.5.3.
Required when ESF equipment is required to be OPERABLE.
=
f Not required to be OPERABLE when reactor steam dome pressure is less than or equal to 100 psig.
The injection function of Drywell Pressure - High and Manual Initiation are not required to be OPERA 8LE with nP indicated reactor vessel water level on the wide range instrument greater than the Level 8'setpoint coincident with the reactor pressure less than 450 psig.
o,
The Loss of Voltage and Degraded Voltage functions are common to Divisions 1, 2 and 3.
TABLE 3.3.3-1 (Continued)
EMERGENCY CORE COOLING SYSTEM ACTUATION INSTRUMENTATION l
]
ACTION ACTION 30 - With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip Function requirement, verify within one hour that a sufficient number of channels remain OPERABLE or are in the tripped condition to maintain automatic actuation capability of either Division 1 or Division 2 ECCS and either ADS Trip System A or Trip System B, and place the inoperable channel (s) in the tripped :ondition within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . Otherwise, declare the associated system (s) inoperable.
i ACTION 31 - With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip Function requirement, verify within one hour that a sufficient number of channels remain OPERABLE to maintain automatic actuation capability of either Division I or Division 2 ECCS and either ADS Trip System A or Trip System B, and restore the inoperable channel (s) to OPERABLE status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .
Otherwise, declare the associated ADS trip system (s) or ECCS inoperable.
i I
ACTION 32 - With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip Function requirement, place the inoperable channel in the tripped condition within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .
l ACTION 33 - With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels p r Trip Function requirement, restore the inoperable channel to OPERABLE status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or declare the l associated ADS Trip System or ECCS inoperable.
ACTION 34 - With the number of OPERABLE channels less than required by the Minimum OPERABLE Char.nels per Trip Function requirement, verify i
within er.: hes, tnat a sufficient number of channels remain OPERABLE or are in the tripped condition to maintain automatic HPCS actuation capability, and place the inoperable channel (s) in the tripped condition within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . Otherwise, declare the HPCS system j
inoperable.
i ACTION 35 - With the number of OPERABLE channels less than required by the j
Minimum OPERABLE Channels per Trip Function requirement, verify within one hour that the HPCS pump suction is either aligned or is capable of automatically realigning to the suppression pool, and place at least one inoperable channel in the tripped condition within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . Otherwise, declare the HPCS system inoperable, j
ACTION 36 - Deleted l
i 1
PERRY - UNIT 1 3/4 3-31 Amendment No. -34; M,-53, 67
TABLE 3.3.3-1 (Continued)
EMERGENCY CORE COOLING SYSTEM ACTUATION INSTRUMENTATION ACTION ACTION 37 - With the number of OPERABLE channels less than the Total Number of Channels, declare the associated emergency diesel generator inoperable and take the ACTION required by Specification 3.8.1.1 or 3.8.1.2, as appropriate.
ACTIDN 38 - With the number of OPERABLE channels less than the Total Number of Channels, place the inoperable channel in the tripped condition within one hour *; operation may then continue until performance of the next required CHANNEL FUNCTIONAL TEST.
i ACTION 39 - With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip Function requirement, verify within one hour that a sufficient number of channels remain OPERABLE to maintain automatic actuation capability of either Division 1 or Division 2 ECCS, and restore the inoperable channel (s) to OPERABLE status within 7 days. Otherwise, declare the associated system (s) inoperable.
ACTION 40 - With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip Function requirement, restore the inoperable channel (s) to OPERABLE status within 7 days. Otherwise, declare the HPCS system inoperable.
The provisions of Specification 3.0.4 are not applicable.
t i
f P
PERRY - UNIT 1 3/4 3-31a Amendment No. 44h 4HL, 67
s
}
TABLE 4.3.3.1-1 x
f EMERGENCY CORE COOLING SYSTEM ACTUATION INSTRUMENTATION SURVEILLANCE REQUIREMENTS E
CHANNEL OPERATIONAL Z
CHANNEL FUNCTIONAL CHANNEL CONDITIONS FOR WHICH TRIP FUNCTION CHECK TEST CALIBRATION SURVEILLANCE REQUIRED A.
DIVISION I TRIP SYSTEM 1.
RHR-A fLPCI MODE) AND LPCS SYSTEM a.
Reactor Vessel Water Level -
Low, level 1 5
Q R(*)
1, 2, 3, 4*, 5*
b.
Drywell Pressure - High 5
Q R(*)
1, 2, 3 c.
LPCS Pump Discharge Flow - Low (Bypass)
S Q
R(*)
1, 2, 3, 4*, 5*
d.
Reactor Vessel Pressure - Low S
Q R(*)
1, 2, 3, 4*, 5*
(LPCS Injection Valve Permissive) e.
Reactor Vessel Pressure - Low S
Q R(*)
1, 2, 3, 4*, 5*
m1 (LPCI Injection Valve Permissive) f.
LPCI Pug A Start Time Delay ma Relay NA Q
Q 1, 2, 3, 4*, 5*
g.
LPCI Pump A Fl a - Low (Bypass)
S Q
R(')
1, 2, 3, 4*, 5*
~
h.
Manual Initiation.
NA R
NA 1, 2, 3, 4*, 5*
2.
AUTOMATIC DEPRESSURIZATION SYSTEM TRIP SYSTEM "A"#
a.
Reactor Vessel Water Level -
Low, level 1 S
Q R(')
I, 2, 3 b.
Manual Inhibit NA Q
NA 1, 2, 3 y
c.
ADS Timer NA Q
Q 1, 2, 3 d.
Reactor Vessel Water Level -
a h
Low, level 3 (Permissive)
S Q
R(*)
1, 2, 3 a
e.
LPCS Pump Discharge Pressure - High (Permissive)
S Q
R(*)
1, 2, 3 g
f.
LPCI Pump A Discharge Pressure - High (Permissive)
S Q
R(*)
1, 2, 3 0
g.
Manual Initiation NA R
~NA 1, 2, 3 i
TABLE 4.3.3.1-1 (Continued) f EMERGENCY CORE COOLING SYSTEM ACTUATION INSTRUMENTATION SURVEILLANCE REQUIREMENTS E
CHANNEL OPERATIONAL Z
CHANNEL FUNCTIONAL CHANNEL CONDITIONS FOR WHICH TRIP FUNCTION CHECK TEST CALIBRATION SURVEILLANCE REQUIRED B.
DIVISION 2 TRIP SYSTEM 1.
RHR B AND C (LPCI MODE) a.
Reactor Vessel Water Level -
Low, level 1 S
Q R(
1, 2, 3, 4*, 5*
b.
Drywell Pressure - High S
Q R(
1, 2, 3 c.
Reactor Vessel Pressure - Low (LPCI Injection Valve Permissive)
S Q
R(*)
1, 2, 3, 4*, 5*
d.
LPCI Pump B Start Time Delay Relay NA Q
Q 1, 2, 3, 4*, 5*
w e.
LPCS Pump Discharge Flow - Low 1
(Bypass)
S Q
R(*)
1, 2, 3, 4*, 5*
f.
Manual Initiation NA R
NA 1, 2, 3, 4*, 5*
i 2.
AUTOMATIC DEPRESSURIZATION SYSTEM TRIP SYSTEM "R"#
a.
Reactor Vessel Water Level -
Low, Level 1 S
Q R(*)
l~,
2, 3 b.
Manual Inhibit NA Q
NA 1, 2, 3 c.
ADS Timer NA Q
Q 1, 2, 3 d.
Reactor Vessel Water Level -
g Low, Level 3 (Permissive)
S Q
R(*)
1, 2, 3 g
e.
LPCI Pump B and C Discharge g-Pressure - High (Permissive)
S Q
R(')
1, 2, 3 '
g f.
Manual Initiation NA R
NA 1, 2, 3 e
y TABLE 4.3.3.1-1 (Continued)
o 7
EMERGENCY CORE COOLING SYSTEM ACTUATION INSTRUMENTATION SURVEILLANCE REQUIREMENTS E
CHANNEL OPERATIONAL U
CHANNEL FUNCTIONAL CHANNEL-CONDITIONS FOR WHICH IRIP FUNCTION CHECK TEST CALIBRATION SURVEILLANCE RE00 BED C.
DIVISION 3 TRIP SYSTEM I.
HPCS SYSTEM i
a.
Reactor Vessel Water Level -
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 m2 Level - High S
Q R(*)
1, 2, 3, 4*, 5*
f.
HPCS Pump Discharge Pressure -
w l
4, High S
Q R(*3 1, 2, 3, 4*, 5*
g.
HPCS System Flow Rate - Low S
Q R(*'
1, 2, 3, 4*, 5*
l h.
Manual Initiation ##
NA R
NA 1, 2, 3, 4*, 5*
1 D.
LOSS OF POWER i
1.
4.16 kV Emergency Bus Under-NA NA R
1, 2, 3, 4**, 5**
voltage (Loss of Voltage) 2.
4.16 kv Emergency Bus Under-S M
R 1, 2, 3, 4**, 5**
voltage (Degraded Voltage)
F
Not required to be OPERABLE when reactor steam dome pressure is less than or equal to 100 psig.
y
The injection function of Drywell Pressure - High and Manual Initiation are not required to be g
OPERABLE with indicated reactor vessel water level on the wide range instrument greater than the Level 8 setpoint coincident with reactor pressure less than 450 psig.
F
When the system is required to be OPERABLE per Specification 3.5.1 or.3.5.3.
Required when ESF equipment is required to be OPERABLE.
O (a) Calibrate trip unit setpoint at least once per 92 days.
-l
.,.-,,w,,.
-,-n--
,-e--+
.--,.nr
,,w-w r
.-a a
INSTRUMENTATION 3/4.3.4 RECIRCULATION PUMP TRIP ACTUATION INSTRUMENTATION ATWS RECIRCULATION PUMP TRIP SYSTEM INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.4.1 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 column of Table 3.3.4.1-2.
APPLICABILITY:
OPERATIONAL CONDITION 1.
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 OPERABLE channels less than required by the Minimum OPERABLE channels per Trip System requirement:
1.
Verify that a sufficient number of channels remain OPERABLE or are in the tripped condition to maintain ATWS-RPT trip capability for:
a) either the low reactor vessel water level or the high reactor vessel pressure Trip Function within one hour, and b) both the low reactor vessel water level and the high reactor vessel pressure Trip Functions within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , and 2.
Place the inoperable channel (s) in the tripped condition within 14 days.
Otherwise, either remove the associated recirculation pump from service or be in at least STARTUP within the next six hours.
SURVEILLANCE REQUIREMENTS 4.3.4.1.1 Each ATWS recirculation pump trip system instrumentation channel shall be demonstrated OPERABLE by the performance of the CHANNEL CHECK, CHANNEL 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 18 months.
PERRY - UNIT 1 3/4 3-40 Amendment No. 67
i
??
e
~
58 i
si TABLE 3.3.4.1-1
.4 ATWS RECIRCULATION PUMP TRIP SYSTEM INSTRUMENTATION' TRIP FUNCTION MINIMUMOPERABLECHANNgLSPER TRIP SYSTEM (*
1.
Reactor Vessel Water Level - Low, level 2 2
2.
Reactor Vessel Pressure - High 2
b (a) When a channel is placed in an inoperable status solely for performance of required Surveillances, l
entry into associated ACTIONS may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the. associated Trip Function usj; maintains ATWS-RPT trip capability.
Br a
CL Et E?
4
-2 m.w+m-,.
e.-
=
c
+--+-,--e
-e->e e
~
1
E TABLE 4.3.4.1-1 y
ATWS RECIRCULATION PUMP TRIP ACTUATION INSTRUMENTATION SURVEILLANCE REQUIREMENTS siZ CHANNEL CHANNEL FUNCTIONAL CHANNEL TRIP FUNCTION CHECK TEST CALIBRATIO_N_
1.
Reactor Vessel Water Level -
Low, Level 2 5
Q R*
2.
Reactor Vessel Pressure - High 5
Q R*
Calibrate trip unit setpoint at least once per 92 days.
5 63 63 C
ea 2a if
. - - _... _.... _ _ _. _ _... ~.. _. -, _ _
i INSTRUMENTATION END-OF-CYCLE RECIRCULATION PUMP TRIP SYSTEM INSTRUMENTATION j
LIMITING CONDITION FOR OPERATION 3.3.4.2 The end-of-cycle recirculation pump trip (EOC-RPT) system instrumentation channels shown in Table 3.3.4.2-1 shall be OPERABLE with their trip setpoints set consistent with the values shown in the Trip Setpoint column of Table 3.3.4.2-2 and with the END-OF-CYCLE RECIRCULATION PUMP TRIP l
SYSTEM RESPONSE TIME as shown in Table 3.3.4.2-3.
APPLICABILITY:
OPERATIONAL CONDITION 1, when THERMAL POWER is greater than or equal to 40% of RATED THERMAL POWER.
i ACTION:
With an end-of-cycle recirculation pump trip system instrumentation a.
channel trip setpoint less conservative than the value shown in the Allowable Values column of Table 3.3.4.2-2, ded are the channel inoperable until the channel is restored to OPERABLE status with the channel setpoint adjusted consistent with the Trip Setpoint value.
b.
With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip System requirement.
1.
Verify that a sufficient number of channels remain OPERABLE or are in the tripped condition to maintain E0C-RPT trip capability for both the turbine stop valve closure and turbine control valve fast closure Trip Functions within two hours, and 2.
Place the inoperable channel (s) in the tripped condition within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .
f i
Otherwise, either remove the associated recirculation pt.p iest i
speed breaker from service or reduce THERMAL POWER to less chan 40%
l of RATED THERMAL POWER within the next 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .
4 PERRY - UNIT I 3/4 3-44 Amendment No. 67
?
.E
[
TABLE 3.3.4.2-1 a:
Z END-OF-CYCLE RECIRCULATION PUMP TRIP SYSTEM INSTRUMENTATION MINIMUM OPERABLE CHANNELS 1 RIP FUNCTION PER TRIP SYSTEM
l.
Turbine Stop Valve - Closure 2*)
2.
Turbine Control Valve - Fast Closure 2*)
R (a) When a channel is placed in an inoperable status solely for performance of required Surveillances, y
entry into associated ACTIONS may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Trip g;
Function maintains EOC-RPT trip capability.
(b) This function is automatically bypassed when turbine first stage pressure is less than the value of turbine first stage pressure corresponding to 40%* of RATED THERMAL POWER.
The Turbine First Stage Pressure Bypass Setpoints and corresponding Allowable Values are adjusted based on Feedwater temperatures (see 3/4.2.2 for definition of AT). The Setpoints and Allowable Values for various ATs are as follows:
y Tf*F)
SetDolnt (Dsia)
Allowable Value fDsia) l E
0-T S 212 s 218 al 0 < AT s 50 5 190 s 196 l
50 < AT s 100 s 168 s 174 g
100 < AT $ 170 s 146 5 152 e
l
~
t y
TABLE 4.3.4.2.1-1 x
7 END-OF-CYCLE RECIRCULATION PUMP TRIP SYSTEM SURVEILLf,9dERGP.ENTS E
CHANNEL Z
FUNCTIONAL CHANNEL TRIP FUNCTION TEST CALIBRATION 1.
Turbine Stop Valve - Closure Q
R 2.
Turbine Control Valve - Fast Closure Q
R tal Et
.c
---e c,..
-,,e w
m---.
cc
~, - -
--es
---n..
,-r
r "U9 5
[
TABLE 3.3.5-1 zZ REACTOR CORE ISOLATION COOLING SYSTEM ACTUATION INSTRUMENTATION MINIMUM OPERABLE CHANNELS FUNCTIONAL UNITS
_PER TRIP SYSTEM (*'
ACTION a.
Reactor Vessel Water Level - Low, level 2 2
50 b.
Reactor Vessel Water level - High, level 8 2 "
51 c.
Condensate Storage Tank Water Level - Low 2(*3 52 d.
Suppression Pool Water level - High 2(*'
52 g
e.
Manual Initiation 1(d' 53
.e.
Yg i
i-(a) When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated ACTIONS may be delayed as follows:
(a) for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Functional Unit e; and (b) for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Functional Units other than e provided the associated Functional Unit maintains RCIC initiation capability.
(b) One trip system with two-out-of-two logic.
(c) One trip system with one-out-of-two logic.
y (d) There is only one manual switch.
l
?.
I E
\\
l 0
l l
i TABLE 3.3.5-1 (Continued)
REACTOR CORE ISOLATION COOLING SYSTEM ACTUATION INSTRUMENTATION ACTION 50 -
With the number of OPERABLE chsnnels less than required by the Minimum OPERABLE Channels per Trip System requirement, verify within one hour that a sufficient number of low reactor vessel water level channels remain OPERABLE or are in the tripped condition to maintain automatic RCIC system actuation capability, and place the inoperable channel (s) in the tripped condition within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . Otherwise, declare the RCIC system inoperable.
ACTION 51 -
With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip System requirement, declare the RCIC system inoperable within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .
l ACTION 52 -
With the number of OPERABLE chanc.els less than required by the Minimum OPERABLE Channels per Trip System requirement, verify within one hour that the RCIC pump suction is aligned or will automatically realign to the suppression pool, and place at least one inoperable channel in the tripped condition within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . Otherwise, declare the RCIC system inoperable.
ACTION 53 -
With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip System requirement, restore the inoperable channel to OPERABLE status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or l
declare the RCIC system inoperable.
PERRY - UNIT 1 3/4 3-52 Amendment No.-40, 67
L y
TABLE 4.3.5.1-1 x
7 REACTOR CORE ISOLATION COOLING SYSTEM ACTUATION INSTRUMENTATION SURVEILLANCE REQUIREMENTS E
CHANNil Z
CHANNEL FUNCTIONAL CHANNEL FUNCTIONAL UNITS
_ CHECK TEST CALIBRATION a.
Reactor Vessel Water Level -
Low, Level 2 S
Q R(')
b.
Reactor Vessel Water Level -
S Q
R(*)
High, level 8 c.
Condensate Storage Tank Level -
Low S
Q R(*)
d.
Suppression Pool Water level -
High S
Q R(')
e.
Manual Initiation NA R
NA w
h (a) Calibrate trip unit setpoint at least once per 92 days.
l N
?.
T l
l t
=.
m TABLE 3.3.6-1 E
CONTROL R00 BLOCK INSTRUMENTATION E
MINIMUM APPLICABLE Z
OPERABLE CHANNELS OPERATIONAL TRIP FUNCTION PER TRIP FUNCTION"'
CONDITIONS ACTION l
1.
R00 PATTERN CONTROL SYSTEM a.
Low Power Setpoint 2
1, 2 60 b.
RWL - High Power Setpoint 2
1 60 2.
APRM a.
Flow Biased Neutron Flux - Upscale 6
1 61 b.
Inoperative 6
1, 2, 5 61 c.
.Downscale 6
1 61 d.
Neutron Flux - Upscale, Startup 6
2, 5 61 3.
SOURCE RANGE MONITORS a.
Detector not full in"'
3 2#
61 w
2**
5 61 1
b.
Upscale *'
3 2f 61 w
2**
5 61 h
c.
Inoperativc")
3 2#
61 2**
5 61 i
d.
Downscale"3 3
2f 61 2**
5 61 4.
INTERMEDIATE RANGE MONITORS a.
Detector not full in 6
2, 5 61 b.
Upscale 6
2, 5 61 c.
Inoperative 6
2, 5 61 d.
Downscale*'
6 2, 5 61 9g 5.
SCRAM DISCHARGE VOLUME g-a.
Water Level - High 2
1, 2, 5*
62 k
6.
REACTOR COOLANT SYSTEM RECIRCULATION FLOW a.
Upscale 6
1 62 2
.o 7.
REf4 TOR MODE SWITCH SHUTDOWN POSITION 2
3, 4 63 l
- ~ _
TABLE 3.3.6-1 (Continued)
CONTROL R00 BLOCK INSTRUMENTATION ACTION ACTION 60 -
Declare the RPCS inoperable and take the ACTION required by Specification 3.1.4.2.
ACTION 61 -
With the n u ber of OPERABLE Channels:
a.
One less than required by the Minimum OPERABLE Channels per Trip Function requirement, restore the inoperable channel to OPERABLE status within 7 days or place the inoperable channel in the tripped condition within the next hour.
b.
Two or more less than required by the Minimum OPERABLE Channels per Trip Function requirement, place at least one inoperable channel in the tripped condition within one hour.
ACTION 62 -
With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip Function requirement, verify within one hour that a sufficient number of channels remain OPERABLE to initiate a rod block by the associated Trip Function, and place at least one inoperable channel in the tripped condition within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .
Otherwise, initiate a rod block.
ACTION 63 -
With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip Function requirement, initiate a rod block.
NOTES
With more than one control rod withdrawn.
Not applicable to control rods removed per Specification 3.9.10.1 or 3.9.10.2.
OPERABLE channels must be associated with SRMs required OPERABLE per Specification 3.9.2.
With IRMs on range 2 or below (a) This function is automatically bypassed if detector count rate is > 100 cps or the IRM channels are on range 3 or higher.
(b) This function is automatically bypassed when the associated IRM channels are on range 8 or higher.
(c) This function is automatically bypassed when the IRM channels are on range 3 or higher.
(d) This function is automatically bypassed when the IRM channels are on range 1.
(e) When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated ACTIONS may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Trip Function maintains control rod block capability.
PERRY - UNIT 1 3/4 3-57 Amendment No. 67
o TABLE 4.3.6-1 9Q CONTROL ROD BLOCK INSTRUMENTATION SURVEILLANCE REOUIREMENTS e
CHANNEL OPERATIONAL 5
CHANNEL FUNCTIONAL CHANNEL CONDITIONS IN WHICH
-i TRIP FUNCTION CHECK TEST C.ALIBRATION(*)
SURVEILLANCE REQUIRED A
1.
R00 PAT 1ERN CONTROL SYSTEM a.
Low Power Setpoint NA S/U(b', Q SAf L2 b.
RWL - High Power Setpoint NA S/U*', Q SAf 1
2.
AERM a.
Flow Biased Neutron Flux - Upscale 1)
Flow Biased NA S/U(b) Q SA(*)
1 2)
High Flow Clamped NA S/U(b',,Q SA(*)
1 b.
Inoperative NA S/U*', Q NA 1' 2' 5 c.
Downscale NA S/U(b', Q M
l d.
Neutron Flux - Upscale, Startup NA S/U*', Q SA 2, 5
[
3.
SOURCE RANGE MONITORS h
S/U(b' M
F'5 a.
Detector not full in NA S/U(b),W(d) b.
Upscale NA tbi,, W R
P 5 c.
Inoperative NA S/U W
M
'5 d.
Downscale NA S/U*',W(d' R
2**,
5 4.
INTERMEDIATE RANGE MONITORS a.
Detector not full in NA S/U*)'W NA b.
Jpscale NA S/U ) W(d)
R S
c.
Inoperative NA.
S/U*),,W NA d.
Downscale NA S/U*),w(d)
R 2,'
5 g
5.
SCRAM DISCHARGE VOLUME a.
Water Level - High NA Q
Rf 1, 2, 5*
l g
6.
REACTOR COOLANT SYSTEM RECIRCULATION FLOW (g
a.
Upscale NA S/U(b'A SA(*)
1 l
7.
REACTOR MODE SWITCH SHUTDOWN POSITION NA R
NA 3, 4
TABLE 8.3.6-1 (Continued)
CONTROL ROD BLGCK INSTRUMENTATION SURVEILLANCE RE0VIREMENTS EqIf1:
a.
Neutron detectors may be excluded from CHANNEL CALIBRATION.
b.
Within 7 days prior to startup.
The CHANNEL CALIBRATION shall exclude the flow reference transmitters, c.
these transmitters shall be calibrated at least once per 18 months..
d.
Trip setpoints are verified during weekly CHANNEL-FUNCTIONAL TESTS.
With more than one control rod withdrawn. Not applicable to control rods removed per Specification 3.9.10.1 or 3.9.10.2.
With IRMs on range 2 or below.
Calibrate trip unit setpoint at least once per 92 days.
l PERRY - UNIT 1 3/4 3-60 Amendment No.-3+, 67 l
INSTRUMENTATION 3/4.3.9 PLANT SYSTEMS ACTUATION INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.9 The plant systems actuation instrumentation channels shown in Table 3.3.9-1 shall be OPERABLE with their trip setpoints set consistent with the values shown in the Trip Setpoint column of Table 3.3.9-2.
APPLICABILITY:
As shown in Table 3.3.9-1.
ACTION:
a.
With a plant system actuation instrumentation channel trip setpJnt less conservative than the value shown in the Allowable Values column of Table 3.3.9-2, 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 one or more plant systems actuation instrumentation channels inoperable, take the ACTION required by Table _3.3.9-1.
SURVEILLANCE RE0VIREMENTS 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.
4.3.9.2 LOGIC SYSTEM FUNCTIONAL TESTS and simulated automatic operation of all channels shall be performed at least once per 18 months.
PERRY - UNIT 1 3/4 3-98 Amendment No. 40, 67
i i
r This page left blank.
I PERRY - UNIT 1 3/4 3-99 Amendment No. -M; 67
TABLE 4.3.9.1-1 EQ PLANT SYSTEMS ACTUATION INSTRUMENTATION SURVEILLANCE REQUIREMENTS CHANNEL OPERATIONAL CHANNEL FUNCTIONAL CHANNEL CONDITIONS IN WHICH TRIP FUNCTION CHECK TEST CALIBRATION SURVEILLANCE REQUIRED
~
1.
CONTAINMENT SPRAY SYSTEM a.
Drywell Pressure - High 5
Q R*
1, 2, 3 b.
Containment Pressure - High S
Q R*
1, 2, 3 c.
Reactor Vessel Water Level -
Low, level 1 S
Q R*
1, 2, 3 t
d.
Timers (1) Subsystem A and B NA Q
R 1, 2, 3 (2) Subsystem B NA Q
R 1, 2, 3 e.
Manual Initiation NA R
NA 1, 2, 3 2.
FEEDWATER SYSTEM / MAIN TURBINE TRIP SYSTEM N
a.
Reactor Vessel Water Level - High,
[
Level 8 5
Q R*
I l
3.
SUPPRESSION POOL MAKEUP SYSTEM a.
Drywell Pressure - High S
Q R*
1, 2, 3 b.
Reactor Vessel Water Level -
Low, Level 1 S
Q R*
1, 2, 3 c.
Suppression Pool Water Level - Low S
Q R*
1, 2, 3 d.
Suppression Pool Makeup Timer NA Q
Q 1, 2, 3 e.
SPMU Manual Initiation NA R
NA 1, 2, 3 a
[
Calibrate trip unit setpoint at least once per 92 days.
l A
F
TABLE 3.3.9-1 (Continued)
{
PLANT SYSTEMS ACTUATION INSTRUMENTATION ACTIONS ACTION 130 -
With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip System requirement, verify within one hour that a sufficient number of channels remain OPERABLE or are in the tripped condition to maintain automatic actuation capability of either subsystem A or subsystem B, and place the inoperable channel (s) in the tripped condition within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . Otherwise, declare the associated subsystem (s) inoperable.
ACTION 131 -
With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip System requirement, verify within one hour that a sufficient number of channels remain OPERABLE to maintain automatic actuation capability of either subsystem A or subsystem 8, and restore the inoperable channel (s) to OPERABLE status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . Otherwise, declare the associated subsystem (s) inoperable.
ACTION 132 -
a.
With the number of OPERABLE Channels one less than required by the Minimum OPERABLE Channels per Trip System requirement, restore the inoperable channel to OPERABLE status within 7 days or be in at least STARTUP within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .
b.
With the number of OPERABLE channels two less than required by the Minimum OPERABLE Channels per Trip System requirement, restore at least one of the inoperable channels 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 within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .
ACTION 133 -
With the number of OPERABLE channels less than required by the Minimum 0PERABLE Channels per Trip System requirement, restore the inoperable channel (s) to OPERABLE status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .
Otherwise, declare the associated subsystem (s) inoperable.
PERRY - UNIT 1 3/4 3-100a Amendment No. 67
TABLE 3.3.9-1 ymj PLANT SYSTEMS ACTUATION INSTRUMENTATION MINIMUM APPLICABLE
.E OPERABLE CHANNELS OPERATIONAL Z
TRIP FUNCTION PER TRIP SYSTEM
CONDITIONS ACTION 1.
CONTAINMENT SPRAY SYSTEM a.
Drywell Pressure - High 2
1, 2, 3 130 b.
Containment Pressure - High 2
1, 2, 3 131-c.
Reactor Vessel Water Level - Low, level 1 2
1, 2, 3 130 d.
Timers (11 SubsystemAandB(10minutetimer) 1 1, 2, 3 131 (2) Subsystem B (1.5 minute timer) 1 1,2,3 131 y
e.
Manual Initiation 1
1,2,3 133 h
2.
FEEDWATER SYSTEM / MAIN TURBINE TRIP SYSTEM 3
a.
Reactor Vessel Water Level - High, level 8 3
1 132 3.
SUPPRESSION POOL MAKEUP SYSTEM a.
Drywell Pressure - High 2
1,2,3 130 b.
Reactor Vessel Water Level - Low, level 1 2
1,2,3 130 c.
Suppression Pool Water i.evel - Low 2
1, 2, 3 131 l
k d.
Suppression Pool Makeup Timer 1
1, 2, 3'
- 131 l
f e.
SPMU Manual Initiation 1
1, 2, 3 133
?>
(a) When a channel is placed in an inoperable status solely for performance of required Surveillances,- entry-L-
into associated ACTIONS may be delayed as follows:
(a) for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Trip Function 1.d.(2); and (b) for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Trip Functions other than 1.d.(2) provided the associated Trip Function maintains E
N Plant Systems actuation capability.
l l
l
REACTOR COOLANT SYSTEM 3/4.4.2 SAFETY VALVES SAFETY / RELIEF VALVES LIMITING CONDITION FOR OPERATION 3.4.2.1 Of the following safety / relief valves, the safety valve function of at least 7 valves and the relief valve function of at least 6 valves other than those satisfying the safety valve function requirement shall be OPERABLE with the specified lift settings:
Number of Valves Function Setooint* (osia) 8 Safety 1165 11.6 psi 6
Safety 1180 11.8 psi 5
Safety 1190 11.9 psi 1
Relief 1103 i 15 psi 9
Relief 1113 i 15 psi 9
Relief 1123 15 psi APPLICABILITY:
OPERATIONAL CONDITIONS 1, 2 and 3.
ACTION:
a.
With the safety and/or relief valve function of one or n: ore of the above required safety / relief valves inoperable, 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.
With one or more safety / relief valves stuck open, close the stuck open safety / relief valve (s); with suppression pool average water temperature 110*F or greater, place the reactor mode switch in the Shutdown position.
c.
With one or more safety / relief valve tail-pipe pressure switches inoperable, restore the inoperable switch (es) to OPERABLE status within 7 days 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 and in COLD SHUT 00WN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .
d.
With either relief valve function pressure actuation trip system "A" or "B" inoperable, restore the inoperable trip system to OPERABLE status within 7 days; otherwise, 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 following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .
SURVEILLANCE RE0VIREMENTS 4.4.2.1.1 The tail-pipe pressure switch for each safety / relief valve shall be demonstrated OPERABLE with the setpoint verified to be 30 i 5 psig by performance of a:
a.
CHANNEL FUNCTIONAL TEST at least once per 92 days, and a l
b.
CHANNEL CALIBRATION at least once per 18 months.
4.4.2.1.2 The relief valve function pressure actuation instrumentation shall be demonstrated OPERABLE # by performance of a:
l a.
CHANNEL FUNCTIONAL TEST, including calibration of the trip unit, at least once per 92 days.
l b.
CHANNEL CALIBRATION, LOGIC SYSTEM FUNCTIONAL TEST ** and simulated automatic operation of the entire system at least once per 18 months.
The lift setting pressure shall correspond to ambient conditions of the valves at nominal operating temperatures and pressures.
SRV solenoid energization shall be used alternating between the "A" solenoid and the "B" solenoid.
When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated ACTIONS may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Function maintains Relief initiation capability.
PERRY - UNIT 1 3/4 4-7 Amendment No. 67
1 l
REACTOR COOLANT SYSTEM SAFETY / RELIEF VALVES LOW-LOW SET FUNCTION LIMITING CONDITION FOR OPERATION i
3.4.2.2 The relief valve function and the low-low set function of the following i
reactor coolant system safety / relief valves shall be OPERABLE with the following settings:
Low-Low Set Function Relief Function Setooint* (osia) i 15 osi Setooint* (osia)
Valve No.
Op_en Close Qp_qn Close e
IB21-F051D 1033 926 1103 15 psi 1003 20 psi IB21-F051C 1073 936 1113 15 psi 1013 20 psi IB21-F051A 1113 946 1113 15 psi 1013 20 psi 1821-F051B 1113 946 1113 15 psi 1013 20 psi IB21-F047F 1113 946 1113 15 psi 1013 20 psi IB21-F051G 1113 946 1113 15 psi 1013 20 psi APPLICABILITY: OPERATIONAL CONDITIONS 1, 2 and 3.
ACTION:
a.
With the relief valve function and/or the low-low set function of one of the above required reactor coolant system safety / relief valves inoperable, restore the inoperable relief valve function and the low-low set function to OPERABLE status within 14 days 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 and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .
b.
With the relief valve function and/or the low-low set function of more than one of the above required reactor coolant system safety / relief valves inoperable, be in at least H0T 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 .
With either relief valve / low-low set function pressure actuation trip system c.
"A" or "B" inoperable, restore the inoperable trip system to OPERABLE status within 7 days; otherwise, 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 following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .
SV3VEILLANCE RE0VIREMENTS 4.4.2.2.1 The relief valve function and the low-low set function pressure actuation instrumentation shall be demonstrated OPERABLE # by performance of a:
l a.
CHANNEL FUNCTIONAL TEST, including calibration of the trip unit, at least once per 92 days.
[
b.
CHANNEL CALIBRATION, LOGIC SYSTEM FUNCTIONAL TEST and simulated automatic operation of the entire system at least once per 18 months.
The lift setting pressure shall correspond to ambient conditions of the valves at nominal operating temperatures and pressures.
When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated ACTIONS may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Function maintains Low-Low Set initiation capability.
PERRY - UNIT 1 3/4 4-8 Amendment No. 67
3/4.3 INSTRUMENTATION BASES 3/4.3.1 REACTOR PROTECTION SYSTEM INSTRUMENTATION The reactor protection system automatically initiates a reactor scram to:
a.
Preserve the integrity of the fuel cladding.
b.
Preserve the integrity of the reactor coolant system.
Minimize the energy which must be absorbed following a loss-of-coolant c.
accident, and d.
Prevent inadvertent criticality.
This specification provides the limiting conditions for operation necessary to preserve the ability of the system to perform its intended function even during periods when instrument channels may be out of service because of maintenance. When necessary, one channel may be made inoperable for brief intervals to conduct required surveillance.
The reactor protection system is made up of two independent trip systems.
There are usually four channels to monitor each parameter with two channels in each trip system. The outputs of the channels in a trip system are combined in a logic so that either channel will trip that trip system. The tripping of both trip systems will produce a reactor scram. The system meets the intent of IEEE-279 for nuclear power plant protection systems.
The bases for the trip settings of the RPS are discussed in the bases for Specification 2.2.1.
Specified surveillance intervals and surveillance and maintenance outage times have been determined in accordance with NEDC-30851P,
" Technical Specification Improvement Analysis for BWR Reactor Protection System," as approved by the NRC and documented in the NRC Safety Evaluation Report (SER) letter to T'. A. Pickens from A. Thadani dated July 15, 1987.
Action b.1 is intended to ensure that appropriate actions are taken if a loss-of-function situation occurs during repairs of multiple, inogerable, untripped instrument channels.
In regards to ACTION b.1, RPS " trip capability is considered to be maintained when each " Functional Unit" identified in Table 3.3.3-1 has sufficient channels OPERABLE or in the tripped condition such that both trig systems will generate a trip signal upon receipt of a valid signal from that Functional Unit" (without the need to consider a further single failure event).
The Functional Units identified in Table 3.3.1-1 are modified by a Note to indicate that when a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated ACTIONS may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , provided the associated Functional Unit maintains trip capabilit Upon completion of the Surveillance, or expiration of the 6 hour6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months allowance, y.the channel must be returned to OPERABLE status or the applicable ACTIONS taken. This Note is based on the RPS reliability analysis assumption that 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months is the average time required to perform channel surveillance. That analysis demonstrated that the 6 hour6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months allowance does not significantly reduce the probability that the RPS will trip when necessary.
The measurement of response time at the specified frequencies provides assurance that the protective functions associated with each channel are completed within the time limit assumed in the safety analyses. No credit was taken for those channels with response times indicated as not applicable.
Response time may be demonstrated by any series of sequential, overlapping, or total channel test measurement, provided such tests demonstrate the total channel res)onse time as defined.
Sensor response time verification may be demonstrated by eitler (1) inplace, onsite or offsite test measurements, or (2) utilizing replacement sensors with certified response times.
PERRY - UNIT 1 B 3/4 3-1 Amendment No. 67
INSTRUMENTATION BASES 3/4.3.2 ISOLATION ACTUATION INSTRUMENTATION This specification ensures the effectiveness of the instrumentation used to mitigate the consequences of accidents by prescribing the OPERABILITY trip setpoints and response times for isolation of the reactor systems.
Specified surveillance intervals and surveillance and maintenance outage times have been determined in accordance with NEDC-30851P, Supplement 2, " Technical Specification Imgrovement Analysis for BWR Instrumentation Ccamon to RPS and ECCS Instrumentation, as approved by the NRC and documented in the NRC Safety Evaluation Report (SER) letter to D.N. Grace from C.E. Rossi dated January 6 1989, and NEDC-31677P, " Technical Specification Improvement Analysis for BWk Isolation Actuation Instrumentation" as approved by the NRC and documented in the NRC SER letter to S.D.
Floyd from C.E. Rossi dated June 18, 1990.
Action c.1 is intended to ensure that appropriate actions are taken if a loss-of-function situation occurs during repairs of multiple, inoperable, untripped instrument channels.
In regards to ACTION c.1, " isolation capability" is considered to be maintained when sufficient channels are OPERABLE or in the tripped condition such that each " Trip Function" identified in Table 3.3.2-1 is capable of isolating the associated piping flow paths upon receipt of a valid signal from that " Trip Function" (without the need to consider a further single failure event ACTION c.1 is not applicable to the Manual Initiation Trip Functions since they). are not assumed in any accident or transient analysis. Thus a total loss of manual initiation capability forupto24 hours (asallowedbyACTIONc.2)ispermitted.
The Trip functions identified in Table 3.3.2-1 are modified by a Note to indicate that when a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated ACTIONS may be delayed as follows:
a other than 5.m provided tne associated Trip Fu(nc) tion maintai for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Trip Function 5.m; and b Upon completion of the Surveillance, or expiration of the 6 hour6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months allowance, the channel must be returned to OPERABLE status or the applicable ACTIONS taken. This Note is based on the reliability analysis assumption that 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months is the average time required to perform channel surveillance. That analysis demonstrated that the 6 hour6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months allowance does not significantly reduce the probability that the isolation will occur when necessary.
Some of the trip settings may have tolerances explicitly stated where both the high and low values are critical and may have a substantial effect on safety.
The setpoints of other instrumentation, where only the high or low end of the setting have a direct bearing on safety, are established at a level away from the normal operating range to prevent inadvertent actuation of the systems involved.
Except for the MSIVs, the safety analysis does not address individual sensor response times or the response times of the logic systems to which the sensors are connected.
For D.C. operated valves, a 3 second delay is assumed before the valve starts to move.
For A.C. operated valves, it is assumed that the A.C. power supply is lost and is restored by startup of the emergency diesel generators.
In this event, a time of 13 seconds is assumed before the valve starts to move.
In addition to the pipe break, the failure of the D.C. operated valve is assumed; thus the signal delay (sensor response) is concurrent with the 13-second diesel startup. The safety analysis considers an allowable inventory loss in each case which in turn determines the valve speed in conjunction with the 13-second delay.
It follows that checking the valve speeds and the 13-second time for emergency power establishment will establish the response time for the isolation functions.
PERRY - UNIT 1 B 3/4 3-2 Amendment No. 67
INSTRUMENTATION BASES 3.4.3.2 ISOLATION ACTVATION INSTRUMENTATION (Continued)
Operation with a trip set less conservative than its Trip Setpoint but within its specified Allowable Value is acceptable on the basis that the difference between each Trip Setpoint and the Allowable Value is an allowance for instrument drift specifically allocated for each trip in the safety analyses.
3/4.3.3 EMERGENCY CORE COOLING SYSTEM ACTUATION INSTRUMENTATION The emergency core cooling system actuation instrumentation is provided to initiate actions to mitigate the consequences of accidents that are beyond the ability of the operator to control. This specification provides the OPERABILITY requirements, trip setpoints and response times that will ensure effectiveness of the systems to provide the design protection. Although the instruments are listed by system, in some cases the same instrument may be used to send the actuation signal to more than one system at the same time.
Specified surveillance intervals and surveillance and maintenance outage times have been datermined in accordance with NEDC-30936P, Part 2, " Technical SpecificationImgruva.catMethodology(withDemonstrationforBWRECCSActuation Instrumentation) as approved by the NRC and documented in the NRC Safety Evaluation Report (SER) letter to D.N. Grace from C.E. Rossi dated December 9, 1988 (Part 2).
ACTIONS 30, 31, 34 35 and 39 contain provisions to ensure that appropriate actions are taken if a loss-of-function situation occurs during repairs of multiple, inoperable, untripped instrument channels.
In regard to ACTIONS 30, 31, 34 and 39,
" automatic actuation capability" is considered to be maintained when sufficient channels are OPERABLE that each " Trip Functio (or are in the tripped condition for ACTIONS 30 and 34) such n" identified in Table 3.3.3-1 is capable of initiating an ECCS function upon receipt of a valid signal from that " Trip Function" (without the need to consider a further single failure event.
Trip Function should be able to initiate either) Division 1 or Division 2; for ADSFor ECCS Divisio Trip Systems A and B, each ADS Trip Function should be able to initiate either Trip System A or Trip System B; and for HPCS, the logic should be able to initiate HPCS.
The Trip Functions identified in Table 3.3.3-1 (except for those in Section D of the Table) are modified by a Note to indicate that when a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated ACTIONS may be delayed as follows:
a for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Trip Functions C.I.f, C.I.g, and C.l.h; and ib) for u(p)to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Trip Functions other than C.l.f, C.I.g, and C.I.h provided the associated Trip Function or the redundant Trip Function (in the other Division) maintains ECCS initiation capability.
Upon completion of the Surveillance, or expiration of th 5 hour5.787037e-5 days 0.00139 hours 8.267196e-6 weeks 1.9025e-6 months allowance, the channel must be returned to OPERABLE status or the applicable ACTIONS taken.
This Note is based on the reliability analysis assumption that 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months is the average time required to perform channel surveillance. That analysis demonstrated that the 6 hour6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months allowance does not significantly reduce the probability that the ECCS will initiate when necessary.
Operation with a trip set less conservative than its Trip Setpoint but within its specified Allowable Value is acceptable on the basis that the difference between each Trip Setpoint and the Allowable Value is an allowance for instrument drift specifically allocated for each trip in the safety analyses.
PERRY - UNIT 1 B 3/4 3-2a Amendment No. 67
INSTRUMENTATION BASES 3/4.3.4 RECIRCULATION PUMP TRIP ACTUATION INSTRUMENTATION The anticipated transient without scram (ATWS) recirculation pump trip system provides a means of limiting the consequences of the unlikely occurrence of a failure to scram during an anticipated transient. The response of the plant to this postulated event falls within the envelope of study events in General Electric Company Topical Report NED0-10349, dated March 1971 and NED0-24222, dated December 1979, and Section 15.8 of the FSAR.
Specified surveillance intervals and surveillance and maintenance outage times have been determined in accordance with GENE-770-06-01, " Bases for C.'.g e tn Surveillance Test Intervals and Allowed Out-0f-Service Times for Selected Instrumentation Technical Specifications" as approved by the NRC and documented in the NRC Safety Evaluation Report (SER) letter to R.D. Binz from C.E. Rossi dated July 21,1992.
The end-of-cycle recirculation pump trip (E0C-RPT) system is an essential safety supplement to the Reactor Protection System. The purpose of the E0C-RPT is to recover the loss of thermal margin which occurs at the end-of-cycle.
The physical phenomenon involved is that the void reactivity feedback due to a pressurization transient can add positive reactivity to the reactor system at a faster rate than the control rods add negative scram reactivity.
Each E0C-RPT system trips both recirculation pumps, reducing coolant flow in order to reduce the void collapse in the core during two of the most limiting pressurization events.
The two events for which the E0C-RPT protective feature will function are closure of the turbine stop valves and fast closure of the turbine control valves.
A fast closure sensor from each of two turbine control valves provides input to the EOC-RPT system; a fast closure sensor from each of the other two turbine control valves provides input to the second E0C-RPT system.
Similarly, a position switch for each of two turbine stop valves provides input to one EOC-RPT system; a position switch from each of the other two stop valves provides input to the other E0C-RPT system.
For each E0C-RPT system, the sensor relay contacts are arranged to form a 2-out-of-2 logic for the fast closure of turbine control valves and a 2-out-of-2 logic for the turbine stop valves.
The operation of either logic will actuate the E0C-RPT system and trip both recirculation pumps.
Specified surveillance intervals and surveillance and maintenance outage times have been determined in accordance with GENE-770-06-01, " Bases for Changes to Surveillance Test Intervals and Allowed Out-Of-Service Times for Selected Instrumentation Technical Specifications" as approved by the NRC and documented in the NRC SER letter to R. D. Binz from C. E. Rossi dated July 21, 1992.
Each E0C-RPT system may be manually bypassed by use of a keyswitch which is administratively controlled. The manual bypasses and the automatic Operating Bypass at less than 40% of RATED THERMAL POWER are annunciated in the control room.
The EOC-RPT system response time is the time assumed in the analysis between initiatbn of valve motion and complete suppression of the electric arc, i.e.,
140ms.
Included in this time are:
the time from initial valve movement to reaching the trip setpoint, the response time of the sensor, the response time of the system logic, and the time allotted for breaker arc suppression.
PERRY - UNIT I B 3/4 3-3 Amendment No. 67
INSTRUMENTATION BASES 3/4.3.4 RECIRCULATION PUMP TRIP ACTUATION INSTRUMENTATION (Continued)
ACTIONS 3.3.4.1.b.1 (ATWS-RPT) and 3.3.4.2.b.1 (End-of-Cycle RPT) are intended to ensure that appropriate actions are taken if a loss-of-function situation occurs during repairs of multiple, inoperable, untripped ATWS-RPT or EOC-RPT instrument channels.
In regard to these ACTIONS, "RPT trip capability" is considered to be maintained when sufficient channels are OPERABLE or in the tripped condition such that each " Trip Function" identified in Table 3.3.4.1-1 (ATWS-RPT) and 3.3.4.2-1 (EOC-RPT) is capable of tripping both recirculation pumps upon receipt of a valid signal from that " Trip Function" (without the need to consider a further single failure event).
The Trip Functions identified in Tables 3.3.4.1-1 and 3.3.4.2-1 are modified by a Note to indicate that when a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated ACTIONS may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , provided the associated Trip Function maintains recirculation pump trip (ATWS or E0C-RPT) capability. Upon completion of the Surveillance, or expiration of the 6 hour6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months allowance, the channel must be returned to OPERABLE status or the applicable ACTIONS taken. This Note is based on the reliability analysis assumption that 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months is the average time required to perform channel surveillance. That analysis demonstrated that the 6 hour6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months allowance does not significantly reduce the probability that the recirculation pumps will trip when necessary.
Operation with a trip set less conservative than its Trip Setpoint but within its specified Allowable Value is acceptable on the basis that the difference between each Trip Setpoint and the Allowable Value is an allowance for instrument drift specifically allocated for each trip in the safety analyses.
PERRY - UNIT 1 B 3/4 3-3a Amendment No. 67
INSTRUMENTATION l
BASES 3/4.3.5 REACTOR CORE ISOLATION COOLING SYSTEM ACTUATION INSTRUMENTATION The reactor core isolation cooling system actuation instrumentation is provided to initiate actions to assure adequate core cooling in the event of
{
reactor isolation from its primary heat sink and the loss of feedwater flow to the reactor vessel.
]
Specified surveillance intervals and surveillance and maintenance outage times have been determined in accordance with NEDC-30936P, Part 2, " Technical
)
Specification Improvement Methodology (with Demonstration for BWR ECCS Actuation Instrumentation)," as approved by the NRC and documented in the NRC Safety Evaluatior. Report (SER) letter to D. N. Grace from C. E. Rossi dated December 9, 1988 (Part 2), and in accordance with GENE-770-06-01, " Bases for Changes to Surveillance Test Intervals and Allowed Out-0f-Service Times for Selected Instrumentation Technical Specifications", and GENE-770-06-02, " Addendum to Bases for Changes to Surveillance Test Intervals and Allowed Out-0f-Service Times for Selected Instrumentation Technical Specifications", which were approved by the NRC and documented in the SER letter to R. D. Binz from C. E. Rossi dated July 21, 1992, and in the SER letter to G. Beck from C. E. Rossi dated September 13, 1991, respectively.
Actions 50 and 52 contain provisions to ensure that appropriate actions are taken if a loss-of-function situation occurs during repairs of multiple, inoperable, untripped instrument channels.
In regards to ACTION 50, RCIC
" automatic actuation capability" is considered to be maintained when sufficient channels are OPERABLE or are in the tripped condition such that each " Functional Unit" identified in Table 3.3.5-1 is capable of initiating the RCIC system upon receipt of a valid signal from that " Functional Unit" (without the need to consider a further single failure event).
The Functional Units identified in Table 3.3.5-1 are modified by a Note to-indicate that when a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated ACTIONS may be delayed as follows:
(a) for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Functional Unit e; and (b) for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Functional Units other than e provided the associated Functional Unit maintains RCIC actuation capability. Upon completion of the Surveillance, or expiration of i
the 6 hour6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months allowance, the channel must be returned to OPERABLE status or the applicable ACTIONS taken. This Note is based on the reliability analysis assumption that 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months is the average time required to perform channel surveillance. That analysis demonstrated that the 6 hour6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months allowance does not significantly reduce the probability that the RCIC System will initiate when necessary.
Operation with a trip set less conservative than its Trip Setpoint but within its specified Allowable Value is acceptable on the basis that the difference between each Trip Setpoint and the Allowable Value is an allowance for instrument drift specifically allocated for each trip in the safety analyses.
3/4.3.6 CONTROL ROD BLOCK INSTRUMENTATIOR The control rod block functions are provided consistent with the requirements of the specifications in Section 3/4.1.4, Control Rod Program Controls and Section 3/4.2 Power Distribution Limits. The trip logic is arranged so that a trip in any one of the inputs will result in a control rod block.
PERRY - UNIT I B 3/4 3-4 Amendment No. 67
REACTOR COOLANT SYSTEM BASES 3/4.3.6 CONTROL R0D BLOCK INSTRUMENTATION (Continued)
Specified surveillance intervals and surveillance and maintenance outage times have been determined in accordance with NEDC-30851P, Supplement 1, " Technical Specification Improvement Analysis for BWR Control Rod Block Instrumentation," as approved by the NRC and documented in the NRC Safety Evaluation Report (SER) letter to D. N. Grace from C. E. Rossi dated September 22, 1988, and in GENE-770-06-01,
" Bases for Changes to Surveillance Test Intervals and Allowed Out-Of-Service Times for Selected Instrumentation Technical Specifications", which were approved by the NRC and documented in the SER letter to R. D. Binz from C. E. Rossi dated July 21, 1992.
ACTION 62 contains provisions to ensure that appropriate actions are taken if a loss-of-function situation occurs during repairs of multiple, inoperable, untripped instrument channels.
In regards to ACTION 62, rod block initiation capability is considered to be maintained when sufficient channels remain OPEPABLE such that each " Trip Function" identified in Table 3.3.6-1 is capable of inserting a rod block upon receipt of a valid signal from that " Trip Function" (without the need to consider a further single failure event).
The Trip Functions identified in Table 3.3.6-1 are modified by a Note to indicate that when a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated ACTIONS may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , provided the associated Trip function maintains control rod block capability. Upon completion of the Surveillance, or expiration of the 6 hour6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months allowance, the channel must be returned to OPERABLE status or the applicable ACTIONS taken.
This Note is based on the reliability analysis assumption that 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months is the average time required to perform channel surveillance.
That analysis demonstrated that the 6 hour6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months allowance does not significantly reduce the probability that the control rod block will occur when necessary.
Operation with a trip set less conservative than its Trip Setpoint but within its specified Allowable Value is acceptable on the basis that the difference between each Trip Setpoint and the Allowable Value is an allowance for instrument drift specifically allocated for each trip in the safety analyses. Adjustments for single recirculation loop operation are made as discussed in the BASES for the APRM Setpoints, Section 2.2.1 Item 2.
3/4.3.7 MONITORING INSTRUMENTATION 3/4.3.7.1 RADIATION MONITORING INSTRUMENTATION The OPERABILITY of the radiation monitoring instrumentation ensures that; (1) the radiation levels are continually measured in the areas served by the individual channels; (2) the alarm or automatic action is initiated when the radiation level trip setpoint is exceeded; and (3) sufficient information is available on selected plant parameters to monitor and assess these variables following an accident. This capability is consistent with 10 CFR Part 50, Appendix A, General Design Criteria 19, 41, 60, 61, 63 and 64.
PERRY - UNIT N0. 1 B 3/4 3-4a Amendment No.-64, 67
d REACTOR COOLANT SYSTEM i
BASES
' 3/4.3.7.2 SEISMIC MONITORING INSTRUMENTATION The OPERABILITY of the seismic monitoring instrumentation ensures that sufficient capability is available to promptly determine the. magnitude of a seismic event and evaluate the response of those features important to safety.
This capability is required to permit comparison of the measured response to that used in the design basis for the unit. This instrumentation is consistent with the recommendations of Regulatory Guide 1.12 " Instrumentation for Earthquakes", April 1974.
3/4.3.7.3 METEOROLOGICAL MONITORING INSTRUMENTATION The OPERABILITY of the meteorological monitoring instrumentation ensures that sufficient meteorological data is available for estimating potential i
radiation doses to the public as a result of routine or accidental release of radioactive materials to the atmosphere. This capability is required to evaluate the need for initiating protective measures to protect the health and safety of the public. This instrumentation is consistent with the recommendations of Regulatory Guide 1.23 "Onsite Meteorological Programs,"
February, 1972.
9 e
PERRY - UNIT 1 B 3/4 3-4h Amendment No.-6+- 67
INSTRUMENTATION BASES MONITORING INSTRUMENTATION (Continued) 3/4.3.9 PLANT SYSTEMS ACTUATION INSTRUMENTATION (Continued) pressure and the feedwater system / main turbine trip system in the event of a failure of the feedwater controller under maximum demand. The LPCI mode of the RHR system is automatically initiated on a high drywell pressure signal and/or a low reactor water level, level 1, signal. The containment spray system will then actuate automatically following high drywell and high containment pressure signals. A 10-minute mininum and a ll.5-minute maximum time delay exists between initiation of LPCI and containment spray actuation.
The suppression pool makeup system is automatically initiated on a low suppression pool water level signal with a concurrent LOCA signal or following a specified time delay after receipt of a LOCA signal.
A high reactor water level, level 8, signal will actuate the feedwater system / main turbine trip system.
Specified surveillance intervals and surveillance and maintenance outage times have been determined in accordance with GENE-770-06-01, " Bases for Changes to Surveillance Test Intervals and Allowed Out-0f-Service Times for Selected Instrumentation Technical Specifications" as approved by the NRC and documented in the NRC Safety Evaluation Report (SER) letter to R.D. Binz from C.E. Rossi dated July 21, 1992.
Actions 130 and 131 contain provisions to ensure that appropriate actions are taken if a loss-of-function situation occurs during repairs of multiple, inoperable, untripped instrument channels.
In regard to these ACTIONS,
" automatic actuation capability" is considered to be maintained when sufficient channels are OPERABLE (or are in the tripped condition for ACTION 130) such that each " Trip Function" identified in Table 3.3.9-1 is capable of actuating their associated Plant system (either Containment Spray subsystem A or subsystem B; or either Suppression Pool Hakeup subsystem A or subsystem B) upon receipt of a valid signal from that " Trip Function" (without the need to consider a further single failure event).
The Trip Functions identified in Table 3.3.9-1 are modified by a Note to indicate that when a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated ACTIONS may be delayed as follows:
(a) for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Trip Function 1.d.(2); and (b) for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Trip Functions other than 1.d.(2) provided the associated Trip Function maintains the appropriate Plant Systems actuation capability. Upon completion of the Surveillance, or expiration of the 6 hour6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months allowance, the channel must be returned to OPERABLE status or the applicable ACTIONS taken. This Note is based on the reliability analysis assumption that 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months is the average time required to perform channel surveillance. That analysis demonstrated that the 6 hour6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months allowance does not significantly reduce the probability that the Plant Systems will initiate when necessary.
PERRY, UNIT 1 B 3/4 3-7 Amendment No. 67
REACTOR COOLANT SYSTEM BASES SAFETY / RELIEF VALVES (Continued)
Demonstration of the safety-relief valve lift settings will occur only during shutdown and will be performed in accordance with the provisions of Specification 4.0.5.
The low-low set system ensures that safety / relief valve discharges are minimized for a second opening of these valves, following any overpressure transient. This is achieved by automatically lowering the closing setpoint of 6 valves and lowering the opening setpoint of 2 valves following the initial opening.
In this way, the frequency and magnitude of the containment blowdown duty cycle is substantially reduced. Suf.icient redundancy is provided for the low-low set system such that failure of any one valve to open or close at its reduced setpoint does not violate the design basis.
Specified surveillance intervals and surveillance and maintenance outage times have been determined in accordance with GENE-770-06-01, " Bases for Changes to Surveillance Test Intervals and Allowed Out-0f-Service Times for Selected Instrumentation Technical Specifications" as approved by the NRC and documented in the NRC Safety Evaluation Report (SER) letter to R. D. Binz from C. E. Rossi dated July 21, 1992.
The Surveillances are modified by a Note to indicate that when a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated ACTIONS may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , provided the associated Function maintains Safety Relief / Low-Low Set capability. Upon completion of the Surveillance, or expiration of the 6 hour6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months allowance, the channel must be returned to OPERABLE status or the applicable ACTIONS taken. This Note is based on the reliability analysis assumption that 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months is the average time required to perform channel surveillance. That analysis demonstrated that the 6 hour6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months allowance does not significantly reduce the probability that the Relief valves / Low-Low Set will initiate when necessary.
3/4.4.3 REACTOR COOLANT SYSTEM LEAKAGE 3/4.4.3.1 LEAKAGE DETECTION SYSTEMS The RCS leakage detection systems required by this specification are provided to monitor and detect leakage from the reactor coolant pressure boundary. These detection systems are consistent with the recommendations of Regulatory Guide 1.45, " Reactor Coolant Pressure Boundary Leakage Detection Systems", May 1973.
PERRY - UNIT 1 B 3/4 4-3 Amendment No. 67
REACTOR COG #1T SYSTEM SASES 0
REACTOR COOLANT SYSTEM LEAKAGE (Continued) 3/4.4.3.2 OPERATIONAL LEAKAGE The allowable leak &ge rates from the reactor coolant system have been based on the predicted and experimentally observed behavior of cracks in pipes. The normally expected background leakage due to equipment design and the detection capability of the instrumentation for determining system leakage was also considered.. The evidence obtained from experiments suggests that for leakage somewhat greater than that specified for UNIDENTIFIED LEAKAGE the probability is small that the imperfection or crack associe ed with such leakage would grow rapidly. However, in all cases, if the leakage rates exceed the values specified or the leakage is located and known to be PRESSURE BOUNDARY LEAKAGE, the reactor will be shutdown to allow further investigation and corrective action.
The Surveillance Requirements for RCS pressure isolation valves provide added assurance of valve integrity thereby reducing the probability of gross valve failure and consequent intersystem LOCA.
Leakage from the RCS pressure isolation valves is IDENTIFIED LEAKAGE and will be considered as a portion of the aL owed limit.
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PERRY - UNIT 1 B 3/4 4-3a Amendment No. 67
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