Text

Amend 79 to License NPF-58,revising TS Re Replacement of Analog Temp Instrumentation Associated W/Leak Detection W/Digital Equipment
	ML20097D522
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Issue date:	01/29/1996
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ATTACHMENT TO LICENSE AMENDMENT NO.79 FACILITY OPERATING LICENSE NO. NPF-58 DOCKET NO. 50-440

\\

l Replace the following pages of the Appendix "A" Technical Specifications including the issued but not yet implemented Improved Technical Specifications (ITS) with the attached pages. The revised pages are identified by Amendment i

number and contain vertical lines indicating the area of change.

l Remove Insert 1-1 1-1 3/4 3-23 3/4 3-23 3/4 3-24 3/4 3-24 3/4 3-25 3/4 3-25 3/4 3-26 3/4 3-26 ITS 3.3-53 ITS 3.3-53

.ITS 3.3-53a ITS 3.3-54 ITS 3.3-54 ITS 3.3-56 ITS 3.3-56 ITS 3.3-57 ITS 3.3-57 ITS 3.3-58 ITS 3.3-58 ITS 3.3-59 ITS 3.3-59 ITS B3.3-170 ITS B3.3-170 ITS B3.3-172 ITS B3.3-172 ITS B3.3-172a 1

i 9602130033 960129 ADOCK0500gO PDR

1.0 DEFINITIONS The following terms are' defined so that uniform interpretation of these specifications may be achieved. The defined tems appear in capitalized type and shall be applicable throughout these Technical Specifications.

ACTION 1.1 ACTION shall be that part of a Specification which prescribes remedial measures required under designated conditions.

AVERAGE PLANAR EXPOSURE 1.2 The AVERAGE PLANAR EXPOSURE shall be applicable to a specific planar height and is equal to the sum of the exposure of all the fuel rods in the specified bundle at the specified height divided by the number of fuel rods in the fuel bundle.

AVERAGE PLANAR LINEAR HEAT GENERATION RATE 1.3 The AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR) shall be applicable to a specific planar height and is equal to the sum of the LINEAR HEAT GENERATION RATES for all the fuel rods in the specified bundle at the specified height divided by the number of fuel rods in the fuel bundle.

CHANNEL CALIBRATION 1.4 A CHANNEL CALIBRATION shall be the adjustment, as necessary, of the channel output such that it responds with the necessary range and accuracy to known values of the parameter which the channel monitors. The CHANNEL CALIBRATION shall encompass the entire channel including the sensor and alarm and/or trip functions, and shall include the CHANNEL FUNCTIONAL TEST. The CHANNEL CALIBRATION may be performed by any series of sequential, overlapping or total channel steps such that the entire channel is calibrated.

CHANNEL CHECK 1.5 A CHANNEL CHECK shall be the qualitative assessment of channel behavior during operation by observation. This determination shall include, where possible, comparison of the channel indication and/or status with other indications and/or status derived from independent instrument channels measuring the same parameter.

CHANNEL FUNCTIONAL TEST 1.6 A CHANNEL FUNCTIONAL TEST shall be:

a.

Analog / digital channels - the injection of a simulated signal into the channel as close to the sensor as practicable to verify OPERABILITY including alarm and/or trip functions and channel failure trips.

b.

Bistable channels - the injection of a simulated signal into the sensor to verify OPERABILITY including alarm and/or trip functions.

The CHANNEL FUNCTIONAL TEST may be performed by any series of sequential, overlapping or total channel steps such that the entire channel is tested.

PERRY - UNIT 1 1-1 Amendment No.79

1 TABLE 4.3.2.1-1 g

ISOLATION ACTUATION INSTRUMENTATION SURVEILLANCE REOUIREMENTS Y

CHANNEL OPERATIONAL 5

CHANNEL FUNCTIONAL CHANNEL CONDITIONS IN WHICH

[

TRIP FUNCTION CHECK TEST CALIBRATION SURVEILLANCE REQUIRED 1.

PRIMARY CONTAINMENT ISOLATION

a. Reactor Vessel Water Level -

Low. Level 2 S

0 R(b) 1, 2. 3 and #

b. Drywell Pressure - High ##

S Q

R(b)

1. 2. 3

c. Containment and Drywell Purge Exhaust Plenum Radiation -

High S

Q R

1, 2. 3 and *

d. Reactor Vessel Water Level -

Low Level 1 S

Q R*

1. 2. 3 and #

e. Manual Initiation NA R

NA

1. 2. 3 and

2.

MAIN STEAM LINE ISOLATION T'

a.

Reactor Vessel Water Level -

0 Low Level 1 S

Q R*

1. 2.'3

b. Main Steam Line Radiation -

High S-0 R

c. Main Steam Line Pressure -

t Low S

Q R(b) 1 d.

Main Steam Line Flow - High S

Q R(b'

1. 2. 3

e. Condenser Vacuum - Low S

Q R*

1.

2**, 3**

f.

Main Steam Line Tunnel i

Temperature - High i

R 1.

Division 1 and 2 S

SA R

1. 2. 3 g

2.

Division 3 and 4 S

O '.

R

1. 2. 3 g.

Main Steam Line Tunnel A Temperature - High 1.

Division 1 and 2 S

SA R

1. 2. 3 if 2.

Division 3 and 4 S

Q R

1. 2. 3

h. Turbine Building Main Steam

~

Line Temperature - High S

Q R

1. 2. 3

i. Manual Initiation NA R

NA

1. 2. 3 n

.: d 0

s i

r

3 5

[

TABLE 4.3.2.1_-1 (Continued) 2]

ISOLATION ACRIATION INSTRUMENTATION SURVEILLANCE REQUIREMENTS CHANNEL OPERATIONAL CHANNEL FUNCTIONAL CHANNEL CONDITIONS IN WHICH TRIP FUNCTION CHECK TEST CALIBRATION SURVEILLANCE REQUIRED 3.

SECONDARY CONTAINMENT ISOLATION

a. Reactor Vessel Water Level - Low. Level 2 S

0 R(b)

1. 2. 3 and #

b. Drywell Pressure - High ##

S Q

R(b)

1. 2. 3

c. Manual Initiation NA R

NA 1, 2. 3 and

R 4.

REACTOR WATER CLEANUP SYSTEM ISOLATION

a. A Flow - High S

0 R-1, 2. 3 y

b. A Flow Timer NA Q

R

1. 2. 3 c.

Equipment Area Temperature -

High S

SA R

1. 2. 3 d.

Equipment Area Ventilation A Temperature - High S

SA R

1. 2. 3

e. Reactor Vessel Water Level - Low. Level 2 S

Q R(*)

1. 2. 3 f.

Main Steam Line Tunnel Ambient Temperature - High S

SA R

1, 2. 3 g.

Main Steam Line Tunnel y

A Temperature - High S

SA R

1. 2. 3 g

h. SLCS Initiation NA Q(

NA

1. 2. 3 g

1.

Manual Initiation NA R

NA 1, 2. 3 8o O

p

=

I s -

2--

m:

e su-,,-,

yw-w e

er es

-wer y

=

um,-

g*

N%

v

o E

S TABLE 4.3.2.1-1 (Continued) l e

g ISOLATION ACTUATION INSTRUMENTATION SURVEILLANCE REQUIREMENTS

[

CHANNEL OPERATIONAL-CHANNEL FUNCTIONAL CHANNEL CONDITIONS IN WHICH TRIP FUNCTION CHECK TEST CALIBRATION SURVEILLANCE REQUIRED i

5.

REACTOR CORE ISOLATION COOLING SYSTEM ISOLATION a.

RCIC Steam Line Flow - High S

0 R(b)

1. 2. 3 l

b.

RCIC Steam Supply Pressure -

Low S

Q R(b'

1. 2. 3 c.

RCIC Turbine Exhaust Diaphragm Pressure - High S

0 R(b' 1, 2. 3 d.

RCIC Equipment Room Ambient i

,g Temperature - High S

SA R

1. 2. 3 l-e.

Deleted Y

f.

Main Steam Line Tunnel Ambient t

0 Temperature - High S

SA R

1. 2. 3 l

[

g.

Main Steam Line Tunnel A Temperature - High S

SA R

1. 2. 3 l

h.

Main Steam Line Tunnel L

Temperature Timer NA SA R

1. 2. 3 l

l i.

RHR Equipment Room Ambient Temperature - High S

SA R

1. 2. 3 l

l j.

RHR Equipment Room A Temperature - High S

SA R

1. 2. 3

)

F k.

RCIC Steam Line Flow

}

High Timer NA 0

R

1. 2. 3 E

1.

Drywell Pressure - High S

0 R(b)

1. 2. 3 E

m.

Manual Initiation NA R

NA

1. 2. 3 5

G l

h l

"a

~ -

-. I

l i

e9g TABLE 4.3.2.1-1 (Continued)

[

ISOLATION ACTUATION INSTRUMENTATION SURVEILLANCE REQUIREMENTS E*

CHANNEL OPERATIONAL 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

SA R

1. 2. 3 l

b.

RHR Equipment Area A Temperature - High S

SA R

1. 2. 3 c.

RHR/RCIC Steam Line g

Flow - High S

Q R(b) 1, 2. 3 y

d.

Reactor Vessel Water Level -

g Low. Level 3 #

S Q

R(b)

1. 2. 3 i

e.

Reactor Vessel (RHR Cut-in Permissive) Pressure - High S

Q R(6'

1. 2. 3 f.

Drywell Pressure - High #

S Q

R(b'

1. 2. 3 g.

Manual Initiation NA R

NA

1. 2. 3 p

When handling irradiated fuel in the primary containment and during CORE ALTERATIONS and operations g

with a potential for draining the reactor vessel.

l g

- When any turbine stop valve is greater than 90% open and/or the key locked bypass switch is g

in the normal position.

- - OPERATIONAL CONDITION 1 or 2 when the mechanical vacuum pump lines are not isolated, o

g

During CORE ALTERATION and operations with a potential for draining the reactor vessel.

(a) Each train or logic channel shall be tested at least every other 92 days.

i (b) Calibrate trip unit set)oint at least once per 92 days.

F

These Trip Functions (1), 3b. 6d. and 6f) utilize instruments which are common to RPS instrumentation.

p

Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 SURVEILLANCE REQUIREMENTS

.._____....__---NOTES-----------------_-----___-----___.-

1.

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

2.

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

SURVEILLANCE FREQUENCY SR 3.3.6.1.1 Perform CHANNEL CHECK.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.3.6.1.2

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

For Function 1.e in Table 3.3.6.1-1 this SR is applicable only to the Division 3 and 4 instruments.

Perform CHANNEL FUNCTIONAL TEST.

92 days SR 3.3.6.1.3 Calibrate the trip unit.

92 days SR 3.3.6.1.4 Perform CHANNEL CALIBRATION.

18 months SR 3.3.6.1.5 Perform LOGIC SYSTEM FUNCTIONAL TEST.

18 months 1

SR 3.3.6.1.6 Verify the ISOLATION SYSTEM RESPONSE TIME 18 months on a for the main steam isolation valves is STAGGERED TEST within limits.

BASIS (continued)

PERRY - UNIT 1 3.3-53 Amendment No. 59,79

Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 SURVEILLANCE FREQUENCY SR 3.3.6.1.7

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

For Function 1.e in Table 3.3.6.1-1, this SR is applicable only to the Division 1 and 2 instruments.

Perform CHANNEL FUNCTIONAL TEST.

184 days i

i l

i 1

PERRY - UNIT 1 3.3-53a Amendment No.79

Primary Containment and Drywell Isolation Instrumentation 1

3.3.6.1 Tabte 3.3.6.1-1 (page 1 of 6)

Primary Contalrunent and Drywell isolation Instrumentation

\\

APPLICABLE CONDITIONS i

MODES OR REQUIRED REFERENCED I

OTHER CHANNELS FROM J

SPECIFIED PER TRIP REQUIRED SURVE!LLANCE ALLOWABLE '

FUNCTION CONDITIONS STSTEM ACTION C.1 REQUIREMENTS VALUE j

1.

Main Steam Line Isolation a.

Reactor vessel Water 1,2,3 2

D SR 3.3.6.1.1 a 14.3 inches Level - Low Low Low, SR 3.3.6.1.2 Level 1 SR 3.3.6.1.3 SR 3.3.6.1.4 SR 3.3.6.1.5 SR 3.3.6.1.6 b.

Main Steam Line 1

2 E

SR 3.3.6.1.1

= 795.0 pois Pressure - Low SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.4 SR 3.3.6.1.5 SR 3.3.6.1.6 c.

Main Steam Line 1,2,3 2 per MSL D

SR 3.3.6.1.1 s 191 paid Flow - High SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.4 SR 3.3.6.1.5 SR 3.3.6.1.6 d.

Condenser vacuun-Low 1,2(a) 2 D

SR 3.3.6.1.1

= 7.6 inches SR 3.3.6.1.2 Hg vacuun 3 *)

SR 3.3.6.1.3 I

SR 3.3.6.1.4 SR 3.3.6.1.5 e.

Main Steam Line Pipe 1,2,3 2

D SR 3.3.6.1.1 s 158.9'F Tunnet SR 3.3.6.1.2 Temperature - High SR 3.3.6.1.4 SR 3.3.6.1.5 l

SR 3.3.6.1.7 f.

Main Steam Line Turbine 1,2,3 2

D SR 3.3.6.1.1 5 138.9'F Building SR 3.3.6.1.2 1

Temperature-4tish SR 3.3.6.1.4 SR 3.3.6.1.5 g.

Manual Initiation 1,2,3 2

G SR 3.3.6.1.5 NA 2.

Primary Containment and Drywell Isolation a.

Reactor vessel Water 1,2,3 2*

H SR 3.3.6.1.1 a 127.6 inches Level-Low Low, Level 2 SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.4 SR 3.3.6.1.5 (continued)

(a) With any turbine stop valve not closed.

(b) Required to initiate the associated drywell isolation function.

l PERRY - UNIT 1 3.3-54 Amendment No. 59, 79

Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 Table 3.3.6.1 1 (page 3 of 6)

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

2.

Primary Containment and Drywell Isolation g.

Containment and (d) 2 K

SR 3.3.6.1.1 s 4.0 sa/hr above Drywell Purge Exhaust SR 3.3.6.1.2 background Plenum Radiation-High SR 3.3.6.1.4 1

(continued)

SR 3.3.6.1.5 h.

Manual Initiation 1,2,3 2*

G SR 3.3.6.1.5 NA (d) 2 K

SR 3.3.6.1.5 NA J

3.

Reactor Core Isolation Cooling (RCIC) System Isolation

]

a.

RCIC Steam Line 1,2,3 1

F SR 3.3.6.1.1 s 298.5 inches Flow - High SR 3.3.6.1.2 water SR 3.3.6.1.3 SR 3.3.6.1.4 SR 3.3.6.1.5 b.

RCIC Steam Line Flow 1,2,3 1

F SR 3.3.6.1.2 a 3 seconds and Time Delay SR 3.3.6.1.4 s 13 seconds SR 3.3.6.1.5 c.

RCIC Steam Supply Line 1,2,3 1

F SR 3.3.6.1.1 a 55 pelg Pressure - Low SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.4 SR 3.3.6.1.5 d.

RCIC Turbine Exhaust 1,2,3 2

F SR 3.3.6.1.1 s 20 psig Diaphragm SR 3.3.6.1.2 Pressure - High SR 3.3.6.1.3 SR 3.3.6.1.4 SR 3.3.6.1.5 e.

RCIC Equipment Area 1,2,3 1

F SR 3.3.6.1.1 s 145.9'F Anblent SR 3.3.6.1.4 I

Tenperature - High SR 3.3.6.1.5 l

SR 3.3.6.1.7 f.

Main Steam Line Pipe 1,2,3 1

F SR 3.3.6.1.1 s 158.9'F Tunnel SR 3.3.6.1.4 I

Tenperature - High SR 3.3.6.1.5 l

SR 3.3.6.1.7 (continued)

(b) Required to initiate the drywell isolation function.

(d) Durfreg CORE ALTERATIONS, operations with a potential for draining the reactor vessel, and movement of irradiated fuel assenblies in primary containment.

PERRY - UNIT 1 3.3-56 Amendment No. 59,79

Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 Table 3.3.6.1 1 (page 4 of 6)

Primary Containment and Drywell Isolation Instruentation APPLICABLE CONDIT!tB MODES OR REFERENGD OTHER REQUIRED FROM SPECIFIED CHANNELS PER REQUIRES SURVEILLANCE ALLOWA8LE FUNCTION CONDITIONS TRIP SYSTFM ACTION C.1 REQUIREMENTS VALUE 3.

RCIC System isolation (continued)

I g.

Main Steam Line Pipe 1,2,3 1

F SR 3.3.6.1.4 s 30 minutes Tunnel Temperature SR 3.3.6.1.5 a

Timer SR 3.3.6.1.7 l

h.

RHR Equipment Area 1,2,3 1 per ares F

SR 3.3.6.1.1 s 159.9'F g

Anblent SR 3.3.6.1.4 Tenperature - High SR 3.3.6.1.5 l

SR 3.3.6.1.7 1.

RCIC/RHR Steam Line 1,2,3 1

F SR 3.3.6.1.1 s 55.6 Flow - High SR 3.3.6.1.2 inches water SR 3.3.6.1.3 SR 3.3.6.1.4 SR 3.3.6.1.5

j. Drywell Pressure - High 1,2,3 1

F SR 3.3.6.1.1 s 1.88 pois SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.4 SR 3.3.6.1.5 k.

Manual Initiation 1,2,3 1

G SR 3.3.6.1.5 NA 4.

Reactor Water Cleanup (RWCU) System Isolation s.

Differential Flow-High 1,2,3 1

F SR 3.3.6.1.1 s 77.1 spo SR 3.3.6.1.2 SR 3.3.6.1.4 SR 3.3.6.1.5 b.

Differentist 1,2,3 1

F SR 3.3.6.1.2 s 10.85 Flow - Timer SR 3.3.6.1.4 minutes l

SR 3.3.6.1.5 c.

RWCU Heat Exchanger 1,2,3 1

F SR 3.3.6.1.1 s 138.9'F g

Room Temperature - HIgh SR 3.3.6.1.4 SR 3.3.6.1.5 l

l SR 3.3.6.1.7 (continued) i i

l

)

i PERRY - UNIT 1 3.3-57 Amendment No. 59,79 I

~

- - =.

Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 Table 3.3.6.1 1 (page 5 of 6)

Primary containment and Drywell Isolation Instrtsnentation APPLICABLE CONDITIONS MODES OR REFERENCED OTHER REQUIRED FROM SPECIFIED CNANNELS PER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS TRIP SYSTEM ACTION C.1 REQUIREMENTS VALUE 4 RWCU System Isolation (continued) d.

RWCU Ptap Rooms 1,2,3 1 per room F

SR 3.3.6.1.1 s 137.9'F g

Temperature - High SR 3.3.6.1.4 SR 3.3.6.1.5 l

4 SR 3.3.6.1.7 e.

RWCU valve Nest Room 1,2,3 1

F SR 3.3.6.1.1 s 137.9'F Tenperature - High SR 3.3.6.1.4 1

4 SR 3.3.6.1.5 l

SR 3.3.6.1.7 f.

RWCU Domineralizer 1,2,3 1

F SR 3.3.6.1.1 s 143.7'F Valve Room SR 3.3.6.1.4 l

Tenperature-High SR 3.3.6.1.5 4

l SR 3.3.6.1.7 g.

RWCU Demin Receiving 1,2,3 1

F SR 3.3.6.1.1 s 143.7'F g

Tank Room SR 3.3.6.1.4 Temperature-High SR 3.3.6.1.5 l

SR 3.3.6.1.7 h.

RWCU Demineralizer Room 1,2,3 1 per room F

SR 3.3.6.1.1 s 143.7'F Temperature-High SR 3.3.6.1.4 5

SR 3.3.6.1.5 l

SR 3.3.6.1.7 1.

Main Steam Line Pipe 1,2,3 1

F SR 3.3.6.1.1 5 158.9'F g

Tunnel Temperature -

SR 3.3.6.1.4 High SR 3.3.6.1.5 SR 3.3.6.1.7 l

J. Reactor vessel Water 1,2,3 2

F SR 3.3.6.1.1 a 127.6 Level-Low Low, Level 2 SR 3.3.6.1.2 inches SR 3.3.6.1.3 SR 3.3.6.1.4 SR 3.3.6.1.5 k.

Standby Liquid Control 1,2 1

1 SR 3.3.6.1.5 NA System Initiation L.

Manual Initiation 1,2,3 2

G SR 3.3.6.1.5 NA (continued)

PERRY - UNIT 1 3.3-58 Amendment No. 59,79

Primary Containment and Drywell Isolation Instrumentation 3.3.6.1 Table 3.3.6.1 1 (page 6 of 6)

Primary Contairment and Dryuell Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REFERENCED OTHER REQU1 RED FROM SPECIFIED CHANNELS PER REQUIRED SURVE!LLANCE ALLOWABLE FUNCTION CONDITIONS TRIP SYSTEM ACTION C.1 REQUIREMENTS VALUE 5.

RHR System Isolation a.

RHR Eppment Area 2 '*,3

1 per area F

SR 3.3.6.1.1 5 159.9'F Ambient SR 3.3.6.1.4 I

Temperature - Nigh SR 3.3.6.1.5 j

l SR 3.3.6.1.7 b.

Reactor vessel Water 1,2'",3'"

2 F

SR 3.3.6.1.1 a 177.1 1

Level-Lew, Level 3 SR 3.3.6.1.2 inches SR 3.3.6.1.3 i

SR 3.3.6.1.4 SR 3.3.6.1.5 l

2,3,4,5 2'"

J SR 3.3.6.1.1 a 177.1 SR 3.3.6.1.2 inches SR 3.3.6.1.3 SR 3.3.6.1.4 SR 3.3.6.1.5 c.

Reactor vesset steam 1,2,3 2

F SR 3.3.6.1.1 s 150 peig Dome Pressure-HIgh SR 3.3.6.1.2 SR 3.611.3 SR 3.6.1.1.4 SR 3.6.1.1.5 d.

Drywet E Pressure - High 1,2,3 2

F SR 3.3.6.1.1 5 1.88 psig SR 3.3.6.1.2 SR 3.3.6.1.3 SR 3.3.6.1.4 SR 3.3.6.1.5 e.

Manual Initiation 1,2,3 2

G SR 3.3.6.1.5 NA (e) With reactor vessel steam dome pressure less than the RHR cut in permissive pressure.

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

(g) With reactor steam dome pressure greater than or equal to the RHR cut in permissive.

PERRY - UNIT 1 3.3-59 Amendment No. 59,79

Primary Containment and Drywell Isolation Instrumentation B 3.3.6.1 BASES SURVEILLANCE SR 3.3.6.1.1 REQUIREMENTS (continued)

Performance of the CHANNEL CHECK once every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ensures that a gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels.

It is based on the assumption that instrument channels monitoring the same approximately the same value. parameter should read Significant deviations between the instrument channels could be an indication of excessive instrument drift in one of the channels or something even more serious. A CHANNEL CHECK will detect gross channel failure: thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION.

Agreement criteria are determined by the plant staff, based on a combination of the channel instrument uncertainties, including indication and readability.

If a channel is outside the criteria, it may be an indication that the instrument has drifted outside its limit. The Frequency is based on operating experience that demonstrates channel failure is rare.

The CHANNEL CHECK supplements less formal, but more frequent, checks of channels during normal operational use of the displays associated with the channels required by the LCO.

SR 3.3.6.1.2 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended function.

Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint methodology.

The quarterly Frequency is based on reliability analysis l

described in References 5 and 6.

For Function 1.e. " Main Steam Line Pipe Tunnel Temperature -

High", this SR is applicable only to the Division 3 and 4 ambient temperature channels. Divisions 1 and 2 are monitored by digital instrument channels, which are functionally tested on a semiannual basis by SR 3.3.6.1.7.

(continued)

PERRY UNIT 1 B 3.3 170 Revision No. 1 Amendment No. 79

Primary Containment and Drywell Isolation Instrumentation B 3.3.6.1 BASES SURVEILLANCE SR 3.3.6.1.6 REQUIREMENTS (continued)

This SR ensures that the 1.ndividual channel response times.

are less than or equal to the maximum values assumed in the accident analysis. Testing is performed only on channels where the assumed response time does not correspond to the diesel generator (DG) start time. For channels assumed to respond within the DG start time, sufficient margin exists in the 10 second start time when compared to the typical channel response time (milliseconds) so as to assure adequate response without a specific measurement test. The instrument response times must be added to the PCIV closure times to obtain the ISOLATION SYSTEM RESPONSE TIME.

ISOLATION SYSTEM RESPONSE TIME acceptance criteria are included in References 7 and 8.

ISOLATION SYSTEM RESPONSE TIME tests are conducted on an 18 month STAGGERED TEST BASIS. This test Frequency is consistent with the typical industry refueling cycle and is based upon plant operating experience that shows that random failures of instrumentation components causing serious response time degradation, but not channel failure, are infrequent.

SR 3.3.6.1.7 A CHANNEL FUNCTIONAL TEST is performed on each required channel to ensure that the entire channel will perform the intended function.

Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint methodology.

Tha semiannual Frequency is based on the reduced drift and the design features inherent in digital systems (Ref. 9).

For Function 1.e. " Main Steam Line Pipe Tunnel Temperature -

High", this SR is applicable only to the Division 1 and 2 ambient temperature channels. Divisions 3 and 4 are monitored by analog instrument channels, which are functionally tested on a quarterly basis by SR 3.3.6.1.2.

(continued)

PEPRY UNIT 1 B 3.3 172 Revision No. 1 Amendment No. 79

Primary Containment and Drywell Isolation Instrumentation B 3.3.6.1 BASES REFERENCES 1.

USAR, Section 6.3.

2.

USAR, Chapter 15.

\\

3.

NED0-31466, " Technical Specification Screening Criteria Application and Risk Assessment,"

i November 1987.

4.

USAR, Section 9.3.5.

5.

NEDC-31677 P A, " Technical Specification Improvement Analysis for BWR Isolation Actuation Instrumentation,"

June 1989.

6.

NEDC-30851-P-A, Supplement 2, " Technical Specifications Improvement Analysis for BWR Isolation Instrumentation Common to RPS and ECCS Instrumentation," March 1989.

i 7.

USAR, Section 15.1.3.

8.

USAR, Section 15.6.

9.

Letter PY-CEI/NRR 1654L, " License Amendment Request:

Replacement of Selected Analog Leak Detection System Instruments with GE NUMAC Leak Detection Monitors,"

November 22, 1993.

i I

i PERRY UNIT 1 B 3.3 172a Revision No. 1 Amendment No. 79 l

ML20097D522

Text

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