Text

Amends 181 & 61 to Licenses DPR-66 & NPF-73,respectively, Revising App a TS Relating to Surveillance Test Intervals
	ML20071Q177
Person / Time
Site:	Beaver Valley
Issue date:	08/08/1994
From:	Butler W; Office of Nuclear Reactor Regulation
To:	;
Shared Package
ML20071Q179	List: ML20071Q177; ML20071Q184;
References
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UNITED STATES 3 f.~

NUCLEAR REGULATORY COMMISSION (f..... j/

WASHINGTON, D.C. 2055W1 f

DUOVESNE LIGHT COMPANY OHIO EDISON COMPANY PENNSYLVANIA POWER COMPANY DOCKET NO. 50-311 BEAVER VALLEY POWER STATION. UNIT NO. I AMENDMENT TO FACILITY OPERATING LICENSE 1

Amendment No.181 License No. DPR-66 1.

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

A.

The application for amendment by Duquesne Light Company, et al. (the licensee) dated October 22, 1993, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act) and the Commission's rules and regulations set forth in 10 CFR Chapter I; B.

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

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; D.

The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and 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.

aS'iei! US$i!*

P

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I 2.

Accordingly, the license is amended by changes to the Technical Specifications as indicated in the attachment to this license amendment, and paragraph 2.C.(2) of Facility Operating License No. DPR-66 is hereby amended to read as follows:

l i

(2) Technical Soecifications The Technical Specifications contained in Appendix A, as revised I

through Amendment No. 181, are hereby incorporated in the license.

The licensee shall operate the facility in accordance with the Technical Specifications.

3.

This license amendment is effective as of the date of its issuance, to be implemented within 60 days of issuance.

FOR THE NUCLEAR REGULATORY COMMISSION i

d-1.s Walter R. Butler, Director i

Project Directorate I-3 Division of Reactor Projects - I/II Office of Nuclear Reactor Regulation

Attachment:

Changes to the Technical Specifications Date of Issuance: August 8, 1994

s ATTACHMENT TO LICENSE AMENDMENT NO.181 FACILITY OPERATING LICENSE NO. DPR-66 DOCKET NO. 50-334 Replace the following pages of Appendix A, Technical Specifications, with the enclosed pages as indicated.

The revised pages are identified by amendment number and contain vertical lines indicating the areas of change.

i Remove Insert 3/4 3-2 3/4 3-2 3/4 3-4 3/4 3-4 3/4 3-5 3/4 3-5 3/4 3-6 3/4 3-6 3/4 3-7 3/4 3-7 3/4 3-11 3/4 3-11 3/4 3-12 3/4 3-12 3/4 3-12a 3/4 3-13 3/4 3-13 3/4 3-15 3/4 3-15 3/4 3-18 3/4 3-18 3/4 3-20 3/4 3-20 3/4 3-21 3/4 3-21 3/4 3-29 3/4 3-29 3/4 3-29a 3/4 3-29a 3/4 3-30 3/4 3-30 3/4 3-31 3/4 3-31 3/4 3-31a 3/4 3-31a 3/4 3-31b deleted B 3/4 3-1 B 3/4 3-1 B 3/4 3-la B 3/4 3-la B 3/4 3-lb

M.

I

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TABLE 3.3-1 DPR-66 REACTOR TRIP SYSTEM INSTRUMENTATION MINIMUM TOTAL NO.

CHANNELS CHANNELS APPLICABLE FUNC HONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION 1.

Manual Reactor Trip 2

1 2

1, 2,

3 (33 12 I

4(3) and S'3 2.

Power Range, Neutron Flux a.

High Setpoint 4

2 3

1, 2

2 b.

Low Setpoint 4

2 3

l'", 2 2

f 9

3.

Power Range, Neutron Flux 4

2 3

1, 2

2 High Positive Rate 4.

Power Range, Neutron Flux 4

2 3

1, 2

2 High Negative Rate S.

Intermediate Range, Neutron 2

1 2

1"),

2, 3('3, 3

i Flux 4( 3 and 5(83 i

f 6.

Source Range, Neutron Flux (Below P-10) a.

Startup 2

1 2

2<2) 3(33, 4

4 (83 and 5(33 b.

Shutdown 2

0 1

3, 4,

and 5 5

7.

Overtemperature AT 3

2 2

1, 2

7 l

8.

Overpower AT 3

2 2

1, 2

7 9.

Pressurizer Pressure-Low 3

2 2

1, 2

7 (Above P-7) t BEAVER VALLEY - UNIT ~1 3/4 3-2 Amendment No.181 1

- ~,.

~ - -. - -.... -

TABLE 3.3-1 (Continued)

DPR-66 REACTOR TRIP SYSTEM INSTRUMENTATION MINIMUM TOTAL NO.

CHANNELS CHANN1LS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION 18.

Turbine Trip (Above P-9) l A. Auto Stop Oil Pressure 3

2 2

1 7

B. Tbrbine Stop Valve 4

4 4

1 8

Closure 19.

Safety Injection Input 2

1 2

1, 2

1 from ESF-20.

Reactor Coolant Pump 1/ breaker 2

1/ breaker 1

11 Breaker Position Trip per (Above P-7) operating loop 21.

Reactor Trip Breakers 2

1 2

1 2,

3(33, 40 I33, 5 (33 2

1 2

4 39 22.

Automatic Trip Logic 2

1 2

1 2,

3(33, 1

l3) 833 2

1 2

4

,5 39 23.

Reactor Trip System Interlocks A.

Intermediate Range 2

1 1

2 3

Neutron Flux, P-6 B.

Power Range 4

2 3

1 12 Neutron Flux, P-8 C.

Power Range-4 2

3 1

12 Neutron Flux, P-9 D.

Power Range 4

2 3

1 12 Neutron Flux, P-10 E. Turbine Impulse 2

1 1

1 12 Chamber Pressure, P-13 BEAVER VALLEY - UNIT 1-3/4 3-4 Amendment No.181

DPR-66 TABLE 3.3-1 (Continued)

TABLE NOTATION (1)

Trip function may be manually bypassed in this Mode above P-10.

(2)

Trip function may be manually bypassed in this Mode above P-6.

(3)

With the reactor trip system breakers in the closed position and l the control rod drive system capable of rod withdrawal.

ACTION STATEMENTS l

ACTION 1 -

With the number of OPERABLE Channels one less than the Minimum Channels OPERABLE requirement, restore the inoperable channel to OPERABLE status within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; however, one channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing per Specification 4.3.1.1.1, provided the other channel is OPERABLE.

ACTION 2 -

With the number of OPERABLE channels one less than the Total Number of

Channels, STARTUP and/or POWER OPERATION may proceed provided the following conditions are satisfied:

a.

The inoperable channel is placed in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , b.

The Minimum Channels OPERABLE requirement is met; however, the inoperable channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing of other channels per Specification 4.3.1.1.1, and c.

Either, THERMAL POWER is restricted to less than or equal to 75 percent of RATED THERMAL POWER and the Power Range Neutron Flux setpoint is reduced to less than or equal to 85 percent of RATED THERMAL POWER within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months ; or, the QUADRANT POWER TILT RATIO is monitored at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months per Specification 4.2.4.c.

ACTION 3 -

With the number of channels OPERABLE one less than required by the Minimum Channels OPERABLE requirement and with the THERMAL POWER level:

a.

Below P-6, restore the inoperable channel to OPERABLE status prior to increasing THERMAL POWER above the P-6 setpoint.

b.

Above P-6 but below 5 percent of RATED THERMAL POWER, l restore the inoperable channel to OPERABLE status prior to increasing THERMAL POWER above 5 percent of l RATED THERMAL POWER.

c.

Above 5

percent of RATED THERMAL

POWER, POWER l OPERATION may continue.

BEAVER VALLEY - UNIT 1 3/4 3-5 Amendment No.181

DPR-66 TABLE 3.3-1 (Continued)

With the number of channels OPERABLE one less than ACTION 4 required by the Minimum Channels OPERABLE requirement and with the THERMAL POWER level:

a.

Below P-6, restore the inoperable channel to OPERABLE status prior to increasing THERMAL POWER above the P-6 setpoint.

b.

Above P-6, operation may continue.

ACTION 5 -

With the number of cnannels OPERABLE one less than required by the Minimum Channels OPERABLE requirement, verify compliance with the SEUTDOWN MARGIN requirements of Specification 3.1.1.1 or Specification 3.1.1.2, as applicable within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months , and at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter.

ACTION 6 -

Not Applicable.

ACTION 7 -

With the number of OPERABLE channels") one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may proceed provided the following conditions are satisfied:

a.

The inoperable channel is placed in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and b.

The Minimum Channels OPERABLE requirement is met; however, the inoperable channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing of other channels per Specification 4.3.1.1.1.

t ACTION 8 -

With the number of OPERABLE channels one less than the Total Number of Channels and with the THERMAL POWER level above P-7, place the inoperable channel in the tripped condition within 6

hours; operation may l continue until performance of the next required CHANNEL FUNCTIONAL TEST.

ACTION 9 -

Not applicable.

l ACTION 10 -

Not applicable.

4 (4)

An OPERABLE hot leg channel consists of: 1) three RTDs per hot l leg, or 2) two RTDs per hot leg with the f ailed RTD disconnected and the required bias applied.

BEAVER VALLEY - UNIT 1 3/4 3-6 Amendment No.181

DPR-66 TABLE 3.3-1 (Continued)

ACTION 11 -

"1th less than the Minimum Number of Channels

OPERABLE, operation may continue provided the inoperable channel is placed in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

l With the number of channels OPERABLE one less than ACTION 12 required by the Minimum Channels OPERABLE requirement, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and/or open the reactor trip breakers.

ACTION 39 -

With the number of OPERABLE channels one less than the Minimum Channels OPERABLE requirement, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or open the reactor trip breakers within the next hour.

ACTION 40 -

a.

With one of the diverse trip features (undervoltage or shunt trip attachment) of a reactor trip breaker inoperable, restore the diverse trip feature to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or declare the breaker inoperable and be in HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months . l Neither breaker shall be bypassed while one of the diverse trip features is inoperable except for the time required for performing maintenance to restore the breaker to OPERABLE status.

b.

With one reactor trip breaker inoperable as a result of something other than an inoperable diverse trip feature; be in at least HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , however, one channel may be bypassed for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing per Specification 4.3.1.1.1, provided l the other channel is OPERABLE.

l BEAVER VALLEY - UNIT 1 3/4 3-7 Amendment No.181 (next page is 3/4 3-9) i

R TABLE 4.3-1 DPR-66 REACTOR TRIP SYSTEM INSTRUMENTATION SURVEILLANCE REOUIREMENTS Channel Modes in Which Channel Channel Functional Surveillance Functional Un.it Check Calibration Test Recuired Utt) 1.

Manual Reactor Trip N.A.

N.A.

S[1*3 N.A.

R I

2.

Power Range, Neutron Flux a.

High Setpoint S

D<a), M(8)

Q 1,

2 l

and Q('8 b.

Low Setpoint S

N.A.

S/U(13 2

4 3.

Power Range, Neutron Flux, N.A.

R Q

1, 2

High Positive Rate 4.

Power Range, Neutron Flux, N.A.

R Q

1, 2

High Negative Rate S.

Intermediate Range, S

N.A.

S/U(13 1

2, 3(l'3, l1* 3, 5(l'8 Neutron Flux 4

S U(13, 2,

3, 4

Q[an 6.

Source Range, Neutron Flux N.A.

N.A.

and 5 (Below P-10) i 7.

Overtemperature AT S

R Q

1, 2

8.

Overpower AT S

R Q

1, 2

9.

Pressurizer Pressure-Low S

R Q

1, 2

10.

Pressurizer Pressure-High S

R Q

1, 2

11.

Pressurizer Water S

R Q

1, 2

Level-High BEA'/ER VALLEY - UNIT 1 3/4 3-11 Amendment No.181

-l

TABLE 4.3-1 (Continued)

DPR-66 REACTOR TRIP SYSTEM INSTRUMENTATION SURVEILLANCE REOUIREMENTS Channel Modes in Which Channel Channel Functional Surveillance Functional Unit Check Calibration Test Reauired 12.

Loss of Flow - Single Loop S

R Q

1 13.

Loss of Flow - Two Loops S

R Q

1 14.

Steam / Generator Water S

R Q

1, 2

Level-Low-Low 15.

Steam Feedwater Flow S

R Q

1, 2

Mismatch and Low Steam Generator Water Level 16.

Undervoltage-Reactor Coolant N.A.

R M

1 Pumps 17.

Underfrequency-Reactor N.A.

R h

1 Coolant Pumps 18.

Turbine Trip

a. Auto Stop Oil Pressure N.A.

N.A.

S/Uu) 1, 2

b. Turbine Stop Valve N.A.

N.A.

S/U"8 1,

2 Closure 19.

Safety Injection Input from N.A.

N.A.

R 1,

2 I

ESF 20.

Reactor Coolant Pump Breaker N.A N.A.

R N.A Position Trip 1,

2, 3 "'),

21.

Reactor Trip Breaker N.A.

N.A.

M('- 118 and S/U")

4 "'),

5 "' 3 i

j BEAVER VALLEY - UNIT 1 3/4 3-12 Amendment No.181

TABLE 4.3-1 (Continued)

DPR-66

~

REACTOR TRIP SYSTEM INSTRUMENTATION SURVEILLANCE REQUIREMENTS Channel Modes in Which Channel Channel Functional Surveillance Functional Unit Check Calibration Test Reauired 22.

Automatic Trip Logic N.A.

N.A.

M"3 1,

2, 3 "*3, 4 "' 3, S "' 3 23.

Reactor Trip System Interlocks A.

P-6 N.A.

N.A.

R 1,

2 B.

P-8 N.A.

N.A.

R 1

C.

P-9 N.A.

N.A.

R 1

D.

P-10 N.A.

N.A.

R 1

E.

P-13 N.A.

R R

1 24.

Reactor Trip Bypass Breakers N.A.

N.A.

M "23, 1,

2, 3 "'3, R"3 3, 4 "' 3, 5 "' '

S/U"3 I

BEAVER VALLEY - UNIT 1 3/4 3-12a Amendment No.181 l

DPR-66 TABLE 4.3-1 (Continued)

NOTATION (1)

If not performed in previous 31 days.

l (2)

Heat balance only, above 15 percent of RATED THERMAL POWER. l (3)

Compare incore to excore axial imbalance above 15 percent of RATED THERMAL POWER. Recalibrate if absolute difference greater than or equal to 3 percent.

(4)

(Not Used)

(5)

Each train tested every other month.

~

(6)

Neutron detectors may be excluded from CHANNEL CALIBRATION.

(7)

Below P-10.

(8)

Below P-6.

(9)

(Not Used) l (10)

The CHANNEL FUNCTIONAL TEST shall independently verify the OPERABILITY of the undervoltage and shunt trip circuits for the Manual Reactor Trip Function.

The test shall also verify the OPERABILITY of the Bypass Breaker trip circuit (s).

(11)

The CHANNEL FUNCTIONAL TEST shall independently verify the OPERABILITY of the undervoltage and shunt trip attachments of the Reactor Trip Breakers.

(12)

Local manual shunt trip prior to placing breaker in service.

(13)

Automatic undervoltage trip.

With the reactor trip system breakers closed and the l (14) control rod drive system capable of rod withdrawal.

BEAVER VALLEY - UNIT 1 3/4 3-13 Amendment No.181

~

TABLE 3.3-3 DPR-66 ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION MINIMUM TOTAL NO.

CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIE OPERABLE MODES ACTION 1.

SAFETY INJECTION AND FEEDWATER ISOLATION

a. Manual Initiation 2

1 2

1, 2,

3, 4

18

b. Automatic Actuation 2

1 2

1, 2,

3, 4

13, 36 Logic

c. Containment 3

2 2

1, 2,

3 14 i

Pressure-High d.

Pressurizer Pressure-Low 3

2 2

1, 2,

14 l

l 3"8 e.

Low Steamline Pressure 3/ loop 2/ loop 2/ loop 1,

2, 14 any loop any loop 3 ")

f 4

BEAVER VALLEY - UNIT 1 3/4 3-15 Amendment No.181

TABT.E 3. 3-3 (Continued)

DPR-66 ENGINEERED SAFETY FEATURE Ai7UATION SYSTEM INSTRUMENTATION MINIMUM TOTAL NO.

CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION 4.

STEAM LINE ISOLATION

a. Manual 2/ steam line 1/ steam 2/ operating 1,

2, 3

18 line steam line

b. Automatic Actuation 2

1 2

1, 2,

3 13 Logic

c. Containment Pressure 3

2 3

1, 2,

3 14 Intermediate-High-High

d. Low Steamline Pressure 1, cop 2/ loop any 2/ loop 1,

2, 14 loop any loop 3("

e. High Steam Pressure Rate 3/Jaop 2/ loop any 2/ operating 3(z) 14 loop loop BEAVER VALLEY - UNIT 1 3/4 3-18 Amendment No.181

=---

c.

DFR-66 TABLE 3.3-3 (Continued)

TABLE NOTATION (1)

Trip function may be bypassed in this MODE below P-11.

l (2)

Trip function automatically bypassed above P-11, and is bypassed l below P-11 when Safety Injection on low steam pressure is not manually bypassed.

ACTION STATEMENTS With the number of OPERABLE Channels one less than the ACTION 13 Minimum Number of Channels, be in at least HOT STANDBY within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months ; however, one channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing per Specification 4.3.2.1.1, provided the other channel is operable.

With the number of OPERABLE Channels one less than the t

ACTION 14 Total Number of

Channels, STARTUP and/or POWER OPERATION may proceed provided the following conditions are satisfied:

a.

The inoperable channel is placed in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

b.

The minimum channels OPERABLE requirement is met; however, the inoperable channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing of other channels per Specification 4.3.2.1.1.

Not applicable.

ACTION 15 With the number of OPERABLE Channels one less than the i

ACTION 16 i

Total Number of Channels, operation may proceed provided the inoperable channel is placed in the bypassed condition and the Minimum Channels OPERABLE requirement is met.

One additional channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing per specification 4.3.2.1.1.

Not applicable.

l ACTION 17

'I With the number of OPERABLE Channels one less than the ACTION 18 Minimum Channels OPERABLE requirement, restore the l

[

inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

l BEAVER VALLEY - UNIT 1 3/4 3-20 Amendment No.181

DPR-66 TABLE 3.3-3 (Continued)

ACTION STATEMENTS ACTION 33 -

With the number of OPERABLE Channels one less than the Total Number of

Channels, the Emergency Diesel Generator associated with the 4kv Bus shall be declared inoperable and the ACTION Statements for Specification 3.8.1.1 or Specification 3.8.1.2, as appropriate, shall apply.

With the number of OPERABLE channels one less than the ACTION 34 Total Number of

Channels, STARTUP and/or POWER OPERATION may proceed provided the following conditions are satisfied:

a.

The inoperable channel is placed in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and b.

The Minimum Channels OPERABLE requirement is met; however, the inoperable channel may be bypassed for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing of other channels per Specification 4.3.2.1.1.

ACTION 36 -

The block of the automatic actuation logic introduced by a reset of safety injection shall be removed by resetting (closure) of the reactor trip breakers within one hour of an inadvertent initiation of safety injection providing that all trip input signals have reset due to stable plant conditions.

Otherwise, the requirements of ACTION statement 13 shall have beenl met.

ACTION 37 -

Not applicable.

l With less than the Minimum Number of Channels ACTION 38 OPERABLE, within one hour determine by observation of the associated permissive annunciator window (s)

(bistable status lights or computer checks) that the interlock is in its required state for the existing plant condition, or apply Specification 3.0.3.

BEAVER VALLEY - UNIT 1 3/4 3-21 Amendment No.181

TABLE 4.3-2 DPR-66 ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION SURVEILLANCE REQUIREMENTS i

CHANNEL MODES IN WHICH CHANFEL CHANNEL FUNCTIONAL SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST REOUIRED 1.

SAFETY INJECTION AND FEEDWATER ISOLATION

}

a. Manual Initiation N.A.

N.A.

Mm 1,

2, 3,

4

b. Automatic Actuation Logic N.A.

N.A.

Mm 1,

2, 3,

4 l

c. Containment Pressure-High S

R Q

1, 2,

3

d. Pressurizer Pressure--Low S

R Q

1, 2,

3

e. Steam Line Pressure--L<3w S

R Q

1, 2,

3 i

t f

?

i 4

f BEAVER VALLEY - UNIT 1 3/4 3-29 Amendment No.181

TABLE 4.3-2 (Continued)

DPR-66 ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION SURVEILLANCE REOUIREMENTS CHANNEL MODES IN WHICH CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST REOUIRED 1.1.

SAFETY INJECTION-TRANSFER FROM INJECTION TO THE RECIRCULATION MODE a.

Manual Initiation N.A.

N.A.

M"3 1,

2, 3,

4 b.

Automatic Actuation N.A.

N.A.

M'*)

1, 2,

3 Logic Coincident with Safety Injection Signal c.

Refueling Water Storage S

R M

1, 2,

3 Tank Level-Low d.

Refueling Water Storage S

R M

1, 2,

3 Tank Level - Auto QS Flow Reduction 2.

CONTAINMENT SPRAY a.

Manual Initiation N.A.

N.A.

M"'

1, 2,

3, 4

b.

Automatic Actuation N.A.

N.A.

M(83 1,

2, 3,

4 Logic c.

Contaiment Pressure-S R

Q 1,

2, 3

l High-High BEAVER VALLEY - UNIT 1 3/4 3-29a Amendment No.181

TABLE 4.3-2 (Continued)

DPR-66 ENGINEERED SAFETY FEATURE ACT"ATION SYSTEM INSTRUMENTATION SURVEILLANCE REOUIREMENTS CHANNEL MODES IN WHICH CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST REOUIRED 3.

CONTAINMENT ISOLATION a.

Phase "A" Isolation

1) Manual N.A.

N.A.

M" 8 1,

2, 3,

4

2) From Safety Injection N.A.

N.A.

M'*3 1,

2, 3,

4 Automatic Actuation Logic b.

Phase "B" Isolation

1) Manual N.A.

N.A.

M"3 1,

2, 3,

4

2) Automatic Actuation N.A.

N.A.

M(23 1,

2, 3,

4 Logic

3) Containment Pressure--

S R

Q 1,

2, 3

l High-High BEAVER VALLEY - UNIT 1 3/4 3-30 Amendment No.181

TABLE 4.3-2 (Continued)

DPR-66

~

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION FURVEILLANCE REOUIREMENTS CHANNEL MODES IN WHICH CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST REOUIRED 4.

STEAM LINE ISOLATION a.

Manual N.A.

N.A.

M"3 1,

2, 3

b.

Automatic Actuation Logic N.A N.A Mc2) 1, 2,

3 c.

Containment Pressure--

S R

Q 1,

2, 3

Intermediate-High-High d.

Steamline Pressure--Low S

R Q

1, 2,

3 e.

Steamline Pressure Rate-High S

R Q

1, 2,

3 5.

TURBINE TRIP AND FEEDWATER ISOLATION a.

Steam Generator Water S

R Q

1, 2,

3 Level--High-High 6.

LOSS OF POWER a.

4.16kv Emergency Bus N.A.

R M

1, 2,

3, 4

Undervoltage (Loss of Voltage)

Trip Feed & Start Diesel b.

4.16kv and 480v Emergency N.A.

R M

1, 2,

3, 4

Bus Undervoltage (Degraded Voltage)

BEAVER VALLEY - UNIT,1 3/4 3-31 Amendment No.181

TABLE 4.3-2 (Continued)

DPR-66

~

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION SURVEILLANCE REOUIREMENTS CHANNEL MODES IN WHICH CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST REOUIRED 7.

AUXILIARY FEEDWATER a.

-Steam Generator Water S

R Q

1, 2, 3 l

Level-Low-Low

[

b.

Undervoltage - RCP S

R M

1, 2 c.

S.I.

See 1 above (all SI surveillance requirements) d.

Emergency Bus N.A.

R R

1, 2,

3 Undervoltage e.

Trip of Main N.A.

N.A.

R 1,

2, 3

Feedwater Pumps 8.

ESF INTERLOCKS a.

P-4 N.A.

N.A.

R 1,

2, 3

l 1

b.

P-11 N.A.

R Q

1, 2,

3 c.

P-12 N.A.

R Q

1, 2,

3 l

l l

BEAVER VALLEY - UNIT 1 3/4 3-31a Amendment No.181

[

DPR-66 3/4.3 INSTRUMENTATION BASES 3 / 4. 3.1 AND 3 / 4. 3. 2 PROTECTIVE AND ENGINEERED SAFETY FEATURES (ESP)

INSTRUMENTATION The OPERABILITY of the protective and ESF instrumentation systems and interlocks ensure that 1) the associated ESF action and/or reactor trip will be initiated when the parameter monitored by each channel or combination thereof exceeds its

setpoint, 2) the specified coincidence logic and sufficient redundancy is maintained to permit a channel to be out of service for testing or maintenance consistent with maintaining an appropriate level of reliability of the Reactor Protection and Engineered Safety Features instrumentation, and 3) sufficient system functional capability is available for protective and ESF purposes from diverse parameters.

The OPERABILITY of these systems is required to provide the overall reliability, redundancy and diversity assumed available in the facility design for the protection and mitigation of accident and transient conditions.

The integrated operation of each of these systems is consistent with the assumptions used in the accident analyses. The surveillance requirements specified for these systems ensure that the overall system functional capability is maintained comparable to the original design standards.

The periodic surveillance tests performed at the minimum frequencies are sufficient to demonstrate this capability.

Specified surveillance intervals and surveillance and maintenance outage times have been determined in accordance with WCAP - 10271, 1

" Evaluation of Surveillance Frequencies and Out of Service Times for i

the Reactor Protection Instrumentation System," and supplements to that report as approved by the NRC and documented in the SER (letter to J.

J.

Sheppard from Cecil O.

Thomas dated February 21, 1985).

Jumpers and lifted leads are not an acceptable method for placing equipment in bypass as documented in the NRC safety evaluation report for this WCAP.

The surveillance requirements for the Manual Trip Function, Reactor Trip Breakers and Reactor Trip Bypass Breakers are provided to reduce the possibility of an Anticipated Transient Without Scram (ATWS) event by ensuring OPEFABILITY of the diverse trip features

(

Reference:

Generic Letter 85-09).

The measurement of response time at the specified frequencies provides assurance that the protective and ESF action function associated with each channel is completed within the time limit assumed in the accident analyses.

No credit was taken in the analyses for those channels with response times indicated as not applicable.

BEAVER VALLEY - UNIT 1 B 3/4 3-1 Amendment No.181

DPR-66 INSTRUMENTATION BASES 2f_4 3.1 and 3/4.3.2 PROTECTIVE AND ENGINEERED SAFETY FEATURES (ESP)

INSTRUMENTATION (Continued)

ESF response times specified in Table 3.3-5 which include sequential l operation of the RWST and VCT valves (NOTES # and ##) are based on values assumed in the Non-LOCA safety analyses.

These analyses take l credit for injection of borated water.

Initial borated water is supplied by the BIT, however, injection of borated water from the RWST is assumed not to occur until the VCT charging pump suction valves are closed following opening of the RWST charging pump suction valves.

When sequential operation of the RWST and VCT valves is not included in the response times (Note

),

the values specified are based on the LOCA analyses.

The LOCA analyses take credit for injection flow regardless of the source.

Verification of the response times specified in Table 3.3-5 will assure that the assumptionc used for the LOCA and Non-LOCA analyses with respect to operation of the VCT and RWST valves are valid.

Response time may be demonstrated by any series of sequential, overlapping or total channel test measurements provided that such tests demonstrate the total channel response time as defined. Sensor response time verification may be demonstrated by either 1) in place, onsite or offsite test measurements or 2) utilizing replacement sensors with certified response times.

The Engineered Safety Feature Actuation System interlocks perform the following functions:

P-4 Reactor tripped Actuates turbine trip, clor,es main feedwater valves on Tavg below setpoint, prevents the opening of the main feedwater valves which were closed by a safety injection or high steam generator water level signal, allows safety injection block so that components can be reset or tripped.

Reactor not tripped prevents manual block of safety injection.

P-11 Above the setpoint P-11 automatically reinstates safety injection actuation on low pressurizer

pressure, automatically blocks steamline isolation on high steam pressure rate, enables safety injection and steamline isolation on low steamline pressure (with Loop Stop Valves Open), and enables autu actuation of the pressurizer PORVs.

BEAVER VALLEY - UNIT 1 B 3/4 3-la Amendment No.181

DPR-66 INSTRUMENTATION BASES

- - - - _ - - -. - _. -. - = - - -. _. _

3/4.3.1 and 3/4.3.2 PROTECTIVE AND ENGINEERED SAFETY FEATURES (ESFi INSTRUMENTATION (Continued)

Below the setpoint P-11 allows the manual block of safety injection actuation on low pressurizer pressure, allows manual block of safety injection and steamline isolation on low steamline pressure (with Loop Stop Valves open) and enabling steamline isolation on high steam pressure rate, automatically disables auto actuation of the pressurizer PORVs unless the Reactor Vessel Over Pressure Protection System is in service.

P-12 Above the setpoint P-12 automatically reinstates an arming signal to the steam dump system.

Below the setpoint P-12 blocks steam dump and allows manual bypass of the steam dump block to cooldown condenser dump valves.

I BEAVER VALLEY - UNIT 1 B 3/4 3-lb Amendment No.181l

fe "ro g a

A A

2 i 3

UNITED STATES l' ~

NUCLEAR REGULATORY COMMISSION (m

/

WASHINGTON, D.C. 20555-0001 6

DV0VESNE LIGHT COMPANY OHIO EDISON COMPANY THE CLEVELAND ELECTRIC ILLUMINATING COMPANY THE TOLEDO ED! SON COMPANY DOCKET NO. 50-412 j

EfAVER VALLEY PO!IER STATION. UNIT 2 1

AME@ MENT TO FACILITY OPERATING LICENSE Amendment No.61 License No. NPF-73

]

1.

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

A.

The application for amendment by Duquesne Light Company, et al. (the licensee) dated October 22, 1993, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act) and the Commission's rules and regulations set forth in 10 CFR Chapter 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 i

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

The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and 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.

l l

4 i

2.

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

Specifications as indicated in the attachment to this license amendment, and paragraph 2.C.(2) of Facility Operating License No. NPF-73 is hereby amended to read as follows:

I (2) Jechnical Soecifications i

The Technical Specifications contained in Appendix A, as revised through Amendment No. 61, and the Environmental Protection Plan j

contained in Appendix B, both of which are attached hereto are hereby incorporated in the license. DLC0 shall operate the facility l

in accordance with the Technical Specifications and the Environmental Protection Plan.

3.

This license amendment is effective as of the date of its issuance, to be implemented within 60 days of issuance.

I FOR THE NUCLEAR REGULATORY COMMISSION J

Walter R. Butler, Director l

Project Directorate I-3 Division of Reactor Projects - I/II l

Office of Nuclear Reactor Regulation

Attachment:

Changes to the Technical Specifications i

Date of Issuance: August 8, 1994 f

1

i ATTACHMENT TO LICENSE AMENDMENT NO.M ZACILITY OPERATING LICENSE NO. NPF-73 DOCKET NO. 50-412 Replace the following pages of Appendix A, Technical Specifications, with the enclosed pages as indicated.

The revised pages are identified by amendment number and contain vertical lines indicating the areas of change.

l Remove Insert 3/4 3-2 3/4 3-2 l

3/4 3-4 3/4 3-4 3/4 3-5 3/4 3-5 3/4 3-6 3/4 3-6 3/4 3-7 3/4 3-7 3/4 3-10 3/4 3-10 j

3/4 3-11 3/4 3-11 3/4 3-12 3/4 3-12 3/4 3-13 3/4 3-13 3/4 3-16 3/4 3-16 3/4 3-18 3/4 3-18 3/4 3-19 3/4 3-19 l

3/4 3-20 3/4 3-20 3/4 3-21 3/4 3-21 3/4 3-22 3/4 3-22 3/4 3-22a 3/4 3-33 3/4 3-33 3/4 3-34 3/4 3-34 3/4 3-35 3/4 3-35 3/4 3-36 3/4 3-36 3/4 3-37 3/4 3-37 B 3/4 3-1 B 3/4 3-1 B 3/4 3-la I

i l

1 l

l TABLE 3.3-1 NPF-73 i

REACTOR TRIP SYSTEM INSTRUMENTATION i

MINIMUM TOTAL NO.

CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION 1.

Manual Reactor Trip 2

1 2

1 2, 3'3',

12 I38 and 5'38 4

i 2.

Power Range, Neutron Flux a.

High Setpoint 4

2 3

1, 2

2 b.

Low Setpoint 4

2 3

1"), 2 2

3.

Power Range, Neutron Flux 4

2 3

1, 2

2 High Positive Rate 4.

Power Range, Neutron Flux 4

2 3

1, 2

2 i

High Negative Rate 5.

Intermediate Rage, Neutron 2

1 2

1"),

2, 3 "3, 3

Flux 4"3 and 5'31 1

6.

Source Range, Neutron Flux (Below P-10) a.

Startup 2

1 2

2'23, 3ca) 4 4 '33 and 5(33 b.

Shutdown 2

1 2

3, 4,

and 5 5

7.

Overtemperature AT 3

2 2

1, 2

7 8.

Overpower AT 3

2 2

1, 2

7 9.

Pressurizer Pressure-Low 3

2 2

1, 2

7 (Above P-7) 10.

Pressurizer Pressure-High 3

2 2

1, 2

7 BEAVER VALLEY - UNIT 2 3/4 3-2 Amendment No.61

TABLE 3.3-1 (Continued)

NPF-73

^

REACTOR TRIP SYSTEM INSTRUMENTATION MINIMUM TOTAL NO.

CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT

-OF CHANNELS TO TRIP OPERABLE MODES ACTION 19.

Safety Injection Input 2

1 2

1, 2

1 from ESF l

20.

Reactor Coolant Pump 1/ breaker 2

1/ breaker 1

11 Breaker Position Trip per (Above P-7) operating loop 21.

Reactor Trip Breakers 2

1 2

1 2,

3'33, 40 2

1 2

4 33, 5 (83 39 22.

Automatic Trip Logic 2

1 2

1 2,

3(33, 1

733, S (33 2

1 2

4 39 23.

Reactor Trip System Interlocks a.

Intermediate Range 2

1 1

2 44 Neutron Flux, P-6

b. Power Range 4

2 3

1 44 i

Neutron Flux, P-8

c. Power Range 4

2 3

1 44 1

Neutron Flux, P-9 i

d. Power Range 4

2 3

1, 2

44 Neutran Flux, P-10

e. Turbine Impulse 2

1 2

1 44 Chamber Pressure, P-13 I

L i

BEAVER VALLEY - UNIT 2 3/4 3-4 Amendment No.61

NPF-73 TABLE 3.3-1 (Continued)

TABLE NOTATION (1)

Trip function may be manually bypassed in this Mode above P-10.

(2)

Trip function may be manually bypassed in this Mode above P-6.

(3)

With the reactor trip system breaxers in the closed position and l the control rod drive system capable of rod withdrawal.

ACTION STATEMENTS ACTION 1 -

With the number of OPERABLE Channels one less than the Minimum Channels OPERABLE requirement, restore the inoperable channel to OPERABLE status within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; however, one channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months i

for surveillance testing per Specification 4.3.1.1.1, provided the other channel is OPERABLE.

ACTION 2 -

With the number of OPERABLE channels one less than the Total Number of

Channels, STARTUP and/or POWER OPERATION may proceed provided the following conditions are satisfied; a.

The inoperable channel is placed in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , b.

The Minimum Channels OPERABLE requirement is met; however, the inoperable channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing of other channels per Specification 4.3.1.1.1, and c.

Either, THERMAL POWER is restricted to less than or equal to 75 percent of RATED THERMAL POWER and the Power Range Neutron Flux sotpoint is reduced to less than or equal to 85 percent of RATED THERMAL POWER within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months ; or, the QUADRANT POWER TILT RATIO is i

monitored at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months per Specification 4.2.4.c.

ACTION 3 -

With the number of channels OPERABLE one less than i

required by the Minimum Channels OPERABLE requirement and with the THERMAL POWER level:

a.

Below P-6, restore the inoperable channel to OPERABLE status prior to increasing THERMAL POWER above the P-6 setpoint.

b.

Above P-6 but below 5 percent of RATED THERMAL POWER, l restore the inoperable channel to OPERABLE status prior to increasing THERMAL POWER above 5 percent of l RATED THERMAL POWER.

c.

Above 5

percent of RATED THERMAL

POWER, POWER l OPERATION may continue.

BEAVER VALLEY - UNIT 2 3/4 3-5 Amendment No. 61

[

l l

NPF-73 TABLE 3.3-1 (Continued) i i

ACTION 4 -

With the number of channels OPERABLE one less than i

required by the Minimum Channels OPERABLE requirement j

and with the THERMAL POWER level:

a.

Below P-6, restore the inoperable channel to OPERABLE status prior to increasing THERMAL POWER above the P-6 lsetpoint and suspend positive reactivity operations.

b.

Above P-6, operation may continue.

i ACTION 5 -

With the number of OPERABLE channels one less than the Minimum Channels OPERABLE reqairement, restore the

}

inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months i

or open the Reactor Trip System breakers, suspend all operations involving positive reactivity changes and i

verify valve 2CHS-91 is closed and secured in position within the next hour.

ACTION 6 -

This Action is not used.

i ACTION 7 -

With the number of OPERABLE channels") one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may proceed provided the following conditions are satisfied:

a.

The inoperable channel is pleced in the tripped

]

condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and b.

The Minimum Channels OPERABLE requirement is. met; howe'.

, the inoperable channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing of other channels per Specification 4.3.1.1.1.

ACTION 8 -

With the number of OPERABLE channels one less than the Total Number of Channels and with the THERMAL POWER level above P-9, place the inoperable channel in the tripped condition within 6

hours; operation may l continue until performance of the next required CHANNEL FUNCTIONAL TEST.

ACTION 9 -

This Action is not used.

ACTION 10 -

This Action is not used.

(4)

An OPERABLE hot leg channel consists of: 1) three RTDs per hot l leg, or 2) two RTDs per hot leg with the failed RTD disconnected i

and the required bias applied.

BEAVER VALLEY - UNIT 2 3/4 3-6 Amendment No.61 1

... -. ~.

NPF-73 TABLE 3.3-1 (Continued)

)

ACTION 11 -

With less than the Minimum Number of Channels

OPERABLE, operation may continue provided the inoperable channel is placed in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

l

]

With the number of channels OPERABLE one less than ACTION 12 required by the Minimum Channels OPERABLE requirement, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and/or open the reactor trip breakers.

With the number of OPERABLE channels one less than the ACTION 39 Minimum Channels OPERABLE requirement, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or open the reactor trip breakers within the next hour.

ACTION 40 -

a.

With one of the diverse trip features (undervoltage or shunt trip attachment) of a reactor trip breaker inoperable, restore the diverse trip feature to OPERABLE status within i

48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or declare the breaker inoperable and be in HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

Neither breaker shall be bypassed while one of I

the diverse trip features is inoperable except for the time required for performing maintenance to restore the breaker to OPERABLE status, b.

With one reactor trip breaker inoperable as a result of something other than an inoperable diverse trip feature, be in at least HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; however, one channel may be bypassed for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing per Specification 4.3.1.1.1, provided l the other channel is OPERABLE.

With less than the Minimum Number of Channels l ACTION 44 OPERABLE, within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months determine by observation of the associated permissive annunciator window (s) that the interlock is in its required state for the existing plant condition, or apply Specification 3.0.3.

i BEAVER VALLEY - UNIT 2 3/4 3-7 Amendment No.61

o TABLE 4. 3-1 NPF-73

~

REACTOR TRIP SYSTEM INSTRUMENTATION SURVEILLANCE REOUIREMENTS Channel Modes in Which Channel Channel Functional Surveillance Functional Unit Check Calibration Test Reauired S U"),

1, 2,

3 "*3, 1.

Manual Reactor. Trip N.A.

N.A.

R[l'8 4 "'), 5 "' 8 4

2..

Power Range, Neutron Flux a.

High Setpoint S

D"), M" 3 Q

1, 2

l and Q"3 b.

Low Setpoint S

R S/U"3 1"), 2 3.

Power Range, Neutron Flux, N.A.

R Q

1, 2

High Positive Rate 4.

Power Range, Neutron Flux, N.A.

R Q

1, 2

High Negative Rate i

5.

Intermediate Range, Neutron S

R S/U"3 1

2, 3 ",

I1' 3, 5"* 3 2

Flux 4

S U"3, 2,

3, 4

Q['8 6.

Source Range, Neutron Flux S

R and 5 (Below P-10) 7.

Overtemperature AT S

R Q

1, 2

8.

Overpower AT S

R Q

1, 2

9.

Pressurizer Pressure-Low S

R Q

1, 2

(Above P-7) 4 10.

Pressurizer Pressure-High S

R Q

1, 2

11.

Pressurizer Water Level-High S

R Q

1, 2

(Above P-7)

BEAVER VALLEY - UNIT 2 3/4 3-10 Amendment No. 61

I 1

TABLE 4.3-1 (Continued)

NPF-73

^

i t

REACTOR TRIP SYSTEM INSTRUMENTATION SURVEILLANCE REOUIREMENTS t

Channel Modes in Which t

i Channel Channel Functional Surveillance Functional Unit Check Calibration Test Reauired f

12.

Loss of Flow - Single Loop S

R Q

1 (Above P-8)

{

13.

Loss of Flow - Two Loop S

R Q

1 (Above P-7 and Below P-8) 14.

Steam / Generator Water Level-S R

Q 1,

2 Low-Low 15.

DELETED.

'16.

Undervoltage-Reactor Coolant N.A.

R M

1

[

Pumps (Above P-7) i 17.

Underfrequency-Reactor N.A.

R M

1 Coolant Pumps (Above P-7) r 18.

Turbine Trip (Above P-9)

A.

Emergency Trip Header N.A.

R S/U"3 1,

2 i

Low Pressure i

B. Turbine Stop Valve N.A.

R S/U"3 1,

2 Closure 19.

Safety Injection Input from N.A.

N.A.

R 1,

2 ESF 20.

Reactor Coolant Pump Breaker N.A N.A.

R N.A Position Trip (Above P-7) 21.

Reactor Trip Breaker N.A.

N.A.

M 1

2, 3 ",

U 1"

l and S/U"3 4 "), 5 "' 8 BEAVER VALLEY - UNIT 2 3/4 3-11 Amendment No. 61 1

-yr-

,,_______.wy-.

m,

,, m.,

y.,~, -.m.

.._m...,,%.._,e

,c

m. -..

,r.r.,.r-~.,

..c-s

._ _ ~ -,-

I l

TABLE 4. 3-1 (Continued)

NPF-73 I

i I

REACTOR TRIP SYSTEM INSTRUMENTATION SURVEILLANCE REOUIREMENTS I

channel Modes in Which Channel Channel Functional Surveillance Functional Unit Check Calibration Test Reauired U) 22.

Automatic Trip Logic N.A.

N.A.

M 1

2, 3 "*),

I1')

5 "' 8 4

1 I

23.

Reactor Trip System Interlocks A.

Intermediate Range N.A.

R R

1, 2

Neutron Flux, P-6 B.

Power Range N.A.

R R

1 i

Neutron Flux, P-8 C.

Power Range N.A.

R R

1 Neutron Flux, P-9 D. Power Range N.A.

R R

1, 2

Neutron Flux, P-10 f

E. Turbine Impulse N.A.

R R

1 Chamber Pressure, P-13 24.

Reactor Trip Bypass Breakers N.A.

N.A.

Muz) 1 2, 3 "'i, I

It' ', 5 "' '

R"8 3,

4 J

J l

BEAVER VALLEY - UNIT 2 3/4 3-12 Amendment No. 61

NPF-73 TABLE 4. 3-1 (Continued)

TABLE NOTATION (1)

If not performed in previous 31 days.

l (2)

Heat balance only, above 15 percent of RATED THERMAL POWER. l Compare incore to excore axial imbalance above 15 percent (3) of RATED THERMAL POWER. Recalibrate if absolute dif ference greater than or equal to 3 percent.

(4)

(Not Used).

Each train tested every other month on a STAGGERED TEST (5)

BASIS.

(6)

Neutron detectors may be excluded from CHANNEL CALIBRATION.

(7)

Below P-10.

(8)

Below P-6.

(Not Used) l (9)

The CHANNEL FUNCTIONAL TEST shall independently verify the (10)

OPERABILITY of the undervoltage and shunt trip circuits for the Manual Reactor Trip Function.

The test shall also verify the OPERABILITY of the Bypass Breaker trip circuit (s).

The CHANNEL FUNCTIONAL TEST shall independently verify the (11)

OPERABILITY of the undervoltage and shunt trip attachments of the Reactor Trip Breakers.

Local manual shunt trip prior to placing breaker in (12) service.

Automatic undervoltage trip.

l (13)

With the reactor trip system breakers closed and the l (14) control rod drive system capable of rod withdrawal.

BEAVER VALLEY - UNIT 2 3/4 3-13 Amendment No.61

TABLE 3.3-3 NPF-73 ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION MINIMUM i

TOTAL NO.

CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION

(

1.

SAFETY INJECTION AND t

FEEDWATER ISOLATION

a. Manual Initiation 2

1 2

1, 2,

3, 4

18

.b. Automatic Actuation 2

1 2

1, 2,

3, 4

13, 36 Logic and Actuation l

Relays

c. Containment 3

2 2

1, 2,

3 14 Pressure-High f

d. Pressurizer 3

2 2

1, 2,

14 Pressure-Low 3cn g

j

e. Steamline Pressure-Low 3/ loop 2/ loop 2/ operating I

2, 14 g3" l

any loop loop 1.1.

SAFETY INJECTION-TRANSFER FROM INJECTION TO THE

-RECIRCULATION MODE

a. Automatic Actuation 2

1 2

1, 2,

3, 4

18 Logic Coincident I

with Safety Injection Signal f

b. Refueling Water 4

2 3

1, 2,

3, 4

16 Storage Tank Level-Extreme Low l

i BEAVER VALLEY - UNIT 2 3/4 3-16 Amendment No. 61

~ -

TABLE 3.3-3 (Continued)

NPF-73

~

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION MINIMUM TOTAL NO.

CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION 4.

STEAM LINE ISOLATION

a. Manual Initiation 1.

Individual 1/ steam line 1/ steam 1/ operating 1,

2, 3

41 line steam line 2.

System 2 sets (2 1 set 2 sets 1,

2, 3

18

+

switches / set) i

b. Automatic Actuation 2

1 2

1, 2,

3 13 Logic

c. Containment Pressure 3

2 2

1, 2,

3 14 Intermediate-High-High

d. Steamline Pressure-Low 3/ loop 2/ loop any 2/ operating 1

2, 14 73" l

loop loop 3 z:

14 l

l t

e. Steamline Pressure

-3/ loop 2/ loop any 2/ operating Rate--High Negative loop loop i

5.

TURBINE TRIP & FEEDWATER ISOLATION

a. Automatic Actuation 2

1 2

1, 2

42 Logic and Actuation Relays

b. Steam Generator 3/ loop 2/ loop in 2/ loop in 1,

2, 3

14 Water Level --

any oper-each oper-High-High, P-14 ating loop ating loop l

BEAVER VALLEY - UNIT 2 3/4 3-18 Amendment No. 61

~

TABLE 3.3-3 (Continued)

NPF-73 ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION MINIMUM TOTAL NO.

CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION 5.

TURBINE TRIP & FEEDWATER ISOLATION (Continued)

c. Safety Injection See Item 1 above for all Safety Injection initiating functions and requirements.

6.

LOSS OF POWER

a. 4.16kv Emergency Bus 1.

Undervoltage 2/4.16kv Bus 2/4.16kV 2/4.16kv 1,

2, 3,

4 33 (Trip Feed)

Bus Bus 2.

Undervoltage 1/4.16kv Bus 1/4.16kv 1/4kv Bus 1,

2, 3,

4 33 (Start Diesel)

Bus

b. 4.16kv Emergency Bus 2/4.16kv Bus 2/ Bus 2/ Bus 1,

2, 3,

4 34 (Degraded Voltage)

c. 480 Volt Emergency Bus 2/480v Bus 2/ Bus 2/ Bus 1,

2, 3,

4 34 (Degraded Voltage) 7.

AUXILIARY FEEDWATERm g

a.

Automatic Actuation 2

1 2

1, 2,

3 42 Logic and Actuation Relays (3)

Manual initiation is included in Specification 3.7.1.2.

l BEAVER VALLEY - UNIT 2 3/4 3-19 Amendment No.61

TABLE 3.3-3 (Continued)

NPF-73 ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION MINIMUM TOTAL NO.

CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION 7.

AUXILIARY FEEDWATER (Continued)

b. Steam Gen. Water Level--

Low-Low 1.

Start Turbine 3/sta. gen.

2/stm gen.

2/sta. gen.

1, 2,

3 14 Driven Pump any stm.

gen.

2.

Start Motor 3/stm. gen.

2/stm gen.

2/sta. gen.

1, 2,

3 14 Driven Pumps any 2 stm.

gen.

c. Undervoltage-RCP (Start (3)-1/ bus 2

2 1,

2 14 Turbine Driven Pump) d.

Safety Injection (Start 1

Motor-Driven Pumps)

See 1 above (all SI initiating functions and requirements) e.

Trip of Main Feedwater 1/ pump 2

2 1,

2, 3

18 I

Pumps (Start Motor I

Driven Pumps) l I

8.

ENGINEERED SAFETY FEATURE INTERLOCKS a.

Reactor Trip, 2

1 2

1, 2,

3 45 P-4 b.

Pressurizer Pressure, 3

2 2

1, 2,

3 38 P-11 c.

Low-Low T.,,

3 2

2 1,

2, 3

38 P-12 BEAVER VALLEY - UNIT 2 3/4 3-20 Amendment No. 61

NPF-73 TABLE 3.3-3 (Continued)

TABLE NOTATION (1)

Trip function may be bypassed in this MODE below P-11.

l (2)

Trip function automatically bypassed above P-11, and is bypassed l below P-11 when Safety Injection on low steam pressure is not manually bypassed.

ACTION STATEMENTS With the number of OPERABLE channels one less than the ACTION 13 Minimum Number of Channels, be in at least HOT STANDBY within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months ;

however, one channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing l per Specification 4.3.2.1.1, provided the other channel is operable.

With the number of OPERABLE channels one less than the ACTION 14 Total Number of

Channels, STARTUP and/or POWER OPERATION may proceed provided the following conditions are satisfied:

a.

The inoperable channel is placed in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

b.

The minimum hannels OPERABLE requirement is met; however, the inoperable channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing of other channels per Specification 4.3.2.1.1.

ACTION 15 -

(This ACTION is not used.)

ACTION 16 -

With the number of OPERABLE Channels one let a t'. an the Total Number of

Channels, operation may proceed provided the inoperable channel is placed in the bypassed condition and the Minimum Channels OPERABLE requirement is met.

One additional channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing per Specification 4.3.2.1.1.

ACTION 17 -

(This ACTION is not used.)

l ACTION 18 -

With the number of OPERABLE Channels one less than the Minimum Channels OPERABLE requirement, restore the l inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

l BEAVER VALLEY - UNIT 2 3/4 3-21 Amendment No. 61

NPF-73 TABLE 3.3-3 (Continued)

ACTION STATEMENTS With the number of OPERABLE Channels one less than the ACTION 33 Total Number of

Channels, the Emergency Diesel Generator associated with the 4kv Bus shall be declared inoperable and the ACTION Statements for specifications 3.8.1.1 or 3.8.1.2, as appropriate, shall apply.

With the number of OPERABLE channels one less than the ACTION 34 Total Number of

Channels, STARTUP and/or POWER OPERATION may proceed provided the following conditions are satisfied:

a.

The inoperable channel is placed in the tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and b.

The Minimum Channels OPERABLE requirement is met; however, the inoperable channel may be bypassed for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance,

testing of other channels per Specification 4.3.2.1.1.

ACTION 36 -

The block of the automatic actuation logic introduced by a reset of safety injection shall be removed by resetting (closure) of the reactor trip breakers within one hour of an inadvertent initiation of safety injection providing that all trip input signals have reset due to stable plant conditions.

Otherwise, the requirements of ACTION Statement 13 shall have been met.

ACTION 37 -

(This ACTION is not used)

ACTION 38 -

With less than the Minimum Number of Channels OPERABLE, within one hour determine by observation of the associated permissive annunciator window (s)

(bistable status lights or computer checks) that the interlock is in its required state for the existing plant condition, or apply Specification 3.0.3.

ACTION 41 -

With the number of OPERABLE Channels one less than the Total Number of Channels, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or declare the associated valve inoperable and take the ACTION required by Specification 3.7.1.5.

BEAVER VALLEY - UNIT 2 3/4 3-22 Amendment No. 61

[

NPF-73 TABLE 3.3-3 (Continued)

ACTION STATEMENTS ACTION 42 -

With the number of OPERABLE Channels one less than the minimum Channels OPERABLE requirement, be in at least HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in at least HOT SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; however, one channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for l

]

surveillance testing per Specification 4.3.2.1.1 provided the other Channel is OPERABLE.

ACTION 45 -

With the number of OPERABLE channels one less than the Total Number of Channels, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in at least HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in at least HOT SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

'T BEAVER VALLEY - UNIT 2 3/4 3-22a Amendment No.61

i TABLE 4.3-2 NPF-73 ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION SURVEILLANCE REOUIREMENTS CHANNEL MODES IN WHICH CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST REOUIRED 1.

SAFETY INJECTION AND FEEDWATER ISOLATION

a. Manual Initiation N.A.

N.A.

M"'

1, 2,

3, 4

b. Automatic Actuation Logic N.A.

N.A.

Mcz) 1, 2,

3, 4

and Actuation Relays

c. Containment Pressure-High S

R Q

1, 2,

3

d. Pressurizer Pressure--Low S

R Q

1, 2,

3 e.

Steam Line Pressure--Low S

R Q

1, 2,

3 i

1.1.

SAFETY INJECTION-TRANSFER FROM INJECTION TO THE I

RECIRCULATION MODE a.

Automatic Actuation N.A.

N.A.

Mczi 1,

2, 3,

4 Logic Coincident with Safety Injection Signal b.

Refueling Water Storage S

R M

1, 2,

3, 4

Tank Level-Extreme Low BEAVER VALLEY - UNIT 2 3/4 3-33 Amendment No.61

)

TABLE 4.3-2 (Continued)

NPF-73

^

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION SURVEILLANCE REOUIREMENTS CHANNEL MODES IN WHICH CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST REOUIRED 2.

CONTAINMENT SPRAY a.

Manual-Initiation N.A.

N.A.

M"3 1,

2, 3,

4 b.

Automatic Actuation N.A.

N.A.

M(23 1,

2, 3,

4 Logic, and Actuation Relays c.

Contaiment Pressure-S R

Q 1,

2, 3

l High-High 3.

CONTAINMENT ISOLATION a.

Phase "A" Isolation 1.

Manual Initiation N.A.

N.A.

M"3 1,

2, 3,

4 2.

Automatic Actuation N.A.

N.A.

Mc2 1,

2, 3,

4 Logic and Actuation Relays f

3.

Safety Injection See Functional Unit 1 above for all Safety Injection Surveillance Requirements.

l i

b.

Phase "B" Isolation I

1.

Manual Initiation N.A.

N.A.

M"3 1,

2, 3,

4 M z:

1, 2,

3, 4 t

2.

Automatic Actuation N.A.

N.A.

Logic and Actuation Relays 3.

Containment Pressure-- S R

Q 1,

2, 3, 4 l

High-High t

BEAVER VALLEY - UNIT 2 3/4 3-34 Amendment No.61

I TABLE 4.3-2 iContinued)

NPF-73 ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION SURVEILLANCE REOUIREMENTS CHANNEL MODES IN WHICH t

CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE l

FUNCTIONAL UNIT CHECK CALIBRATION TEST REOUIRED l

4.

STEAM LINE ISOLATION l

a.

Manual Initiation 1.

Individual N.A.

N.A.

M"3 1,

2, 3

i 2.

System N.A.

N.A.

M"3 1,

2, 3

b.

Automatic Actuation Logic N.A N.A Mz 1,

2, 3

i i

and Actuation Relays c.

Containment Pressure--

S R

Q 1,

2, 3

Intermediate-High-High i

d.

Steamline Pressure--Low S

R Q

1, 2,

3 e.

Steamline Pressure Rate-High S

R Q

1, 2,

3 Negative 4

5.

TURBINE TRIP AND FEEDWATER l

ISOLATION a.

Automatic Actuation Logic N.A N.A M<z 1,

2, 3

and Actuation Relays b.

Steam Generstor Water S

R Q

1, 2,

3 l

)

Level--Higit a ligh, P-14 l

c.

Safety Injection See Functional Unit I above for all Safety Injection Surveillance Requirements.

r d

l BEAVER VALLEY - UNIT 2 3/4 3-35 Amendment No.61 l

J

TABLE 4.3-2 (Continued)

NPF-73

^

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION SURVEILLANCE REOUIREMENTS CHANNEL MODES IN WHICH CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST REOUIRED 6.

LOSS OF POWER a.

4.16kv Emergency Bus

1. Undervoltage (Trip Feed)

N.A.

R M

1, 2,

3, 4

l 2.

Undervoltage (Start Diesel)

N.A.

R M

1, 2,

3, 4

b.

4.16kv Emergency N.A.

R H

1, 2,

3, 4

Bus (Degraded Voltage) c.

480v Emergency Bus N.A.

R M

1, 2,

3, 4

(Degraded Voltage) 7.

AUXILIARY FEEDWATER")

l a.

Automatic Actuation Logic N.A N.A.

Mca) 1, 2,

3 and Actuation Relays b.

Steam Generator Water Level-Low-Low 1.

Start Turbine Driven S

R Q

1, 2,

3 l

Pump 2.

Start Motor Driven S

R Q

1, 2,

3 l

Pumps (4)

Manual initiation is included in Specification 4.7.1.2.

l BEAVER VALLEY - UNIT 2 3/4 3-36 Amendment No.61

5 TABLE 4.3-2 (Continued)

NPF-73 t

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION SURVEILLANCE REOUIREMENTS i

CHANNEL MODES IN WHICH i

i CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST REOUIRED 7.

AUXILIARY FEEDWATER (continued) l t

c.

Undervoltage - RCP (Start S

R M

1, 2

Turbine-Driven Pump) d.

Safety Injection (Start See 1 above (all SI surveillance requirements)

Motor-Driven Pumps) f e

Trip of Main N.A.

N.A.

R 1,

2, 3

Feedwater Pumps (Start Motor-Driven Pumps) l 8.

ENGINEERED SAFETY FEATURE INTERLOCKS a.

Reactor Trip, P-4 N.A N.A.

RU3 1,

2, 3

b.

Pressurizer Pressure, P-11 N.A.

R Q

1, 2,

3

}

c.

Low-Low T.,,,

P-12 N.A.

R Q

1, 2,

3 1

i f

i l

i i

i BEAVER VALLEY - UNIT 2 3/4 3-37 Amendment No.61

NPF-73 3/4.3 INSTRUMENTATION BASES 3/4.3.1 and 3/4.3.2 REACTOR TRIP SYSTEM AND ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION The OPERABILITY of the Reactor Protection System and Engineered Safety Feature Actuation System Instrumentation and interlocks ensure that 1) the associated action and/or reactor trip will be initiated when the parameter monitored by each channel or combination thereof reaches its

setpoint, 2) the specified coincidence logic and sufficient redundancy is maintained to permit a channel to be out of service for testing or maintenance consistent with maintaining an appropriate level of reliability of the Reactor Protection and Engineered Safety Features instrumentation, and 3) sufficient system functional capability is available from diverse parameters.

The CPERABILITY of these systems is required to provide the overall reliability, redundancy, and diversity assumed available in the facility design for the protection and mitigation of accident and transient conditions. The integrated operation of each of these systems is consistent with the assumptions used in the accident analyses. The surveillance requirements specified for these systems ensure that the overall system functional capability is maintained comparable to the original design standards.

The periodic surveillance tests performed at the minimum frequencies are sufficient to demonstrate this capability.

Specified surveillance intervals and surveillance and maintenance outage times have been determined in accordance with WCAP

- 10271, " Evaluation of Surveillance Frequencies and Out of Service Times for the Reactor Protection Instrumentation System,"

and supplements to that report as approved by the NRC and documented in the SER (letter to J. J. Sheppard from Cecil O. Thomas dated February 21, 1985).

Jumpers and lif ted leads are not an acceptable method for placing equipment in bypass as documented in the NRC safety evaluation report for this WCAP.

The Engineered Safety Feature Actuation System Instrumentation Trip Setpoints specified in Table 3.3-4 are the nominal values at which the bistables are set for each functional unit. A setpoint is considered to be adjusted consistent with the nominal value when the "as measured" setpoint is within the band allowed for calibration accuracy.

To accommodate the instrument drift assumed to occur between operational tests and the accuracy to which setpoints can be measured and calibrated, Allowable Values for the setpoints have been specified in Table 3.3-4. Operation with setpoints less conservative than the Trip Setpoint but within the Allowable Value is acceptable BEAVER VALLEY - UNIT 2 B 3/4 3-1 Amendment No.61

a NPF-73 3/4.3 INSTRUMENTATION BASES 3/4.3.1 and 3/4.3.2 REACTOR TRIP SYSTEM AND ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION (Continued) since an allowance has been made in the safety analysis to accommodate this error. An optional provision has been included for determining the OPERABILITY of a channel when its trip setpoint is found to exceed the Allowable Value. The methodology of this option utilizes the "as measured" deviation from the specified calibration point for rack and sensor components in conjunction with a

statistical combination of the other uncertainties of the instrumentation to mes.sure the process variable and the uncertainties in calibrating the instrumentation.

In Equation 2.2-1, Z+R+S$

TA, the interactive effects of the errors in the rack and the sensor, and the "as measured" values of the errors are considered.

Z, as specified in Table 3.3-4, in percent span, is the statistical summation of errors assumed in the analysis excluding those associated with the sensor and rack drift and the accuracy of their measurement. TA or Total Allowance is the difference, in percent span, between the trip setpoint and the value used in the analysis for the actuation. R or Rack Error is the "as measured" deviation, in percent span, for the affected channel from the specified trip setpoint.

S or Sensor Drift is either the "as measured" deviation of the sensor from its calibration point or the value specified in Table 3.3-4, in percent span, from the analysis assumptions.

Use of Equation 2.2-1 allows for a sensor drift factor, an increased rack drift factor, and provides a threshold value for REPORTABLE EVENTS.

BEAVER VALLEY - UNIT 2 B 3/4 3-la Amendment No.61 l

ML20071Q177

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