Text

Amends 130 & 128 to Licenses DPR-80 & DPR-82,respectively, Revising Combined TS for Dcnpp by Adding Lco,Trip Setpoints & Surveillance Requirements for Residual Heat Removal Pump Trip on Refueling Water Storage Tank level-low
	ML20205B670
Person / Time
Site:	Diablo Canyon
Issue date:	03/26/1999
From:	Steven Bloom; NRC (Affiliation Not Assigned)
To:	;
Shared Package
ML20205B676	List: ML20205B670;
References
	NUDOCS 9903310324
	Download: ML20205B670 (14)
	v • d • e

...

p Kf7 UNITED STATES l

S NUCLEAR REGULATORY COMMISSION f

WASHINGTON, D.C. 20615 0001

% * * * * * +'

PACIFIC GAS AND ELECTRIC COMPANY DOCKET NO. 50-275 DIABLO CANYON NUCLEAR POWER PLANT. UNIT NO.1 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No.130 License No. DPR-80 j

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

A. The application for amendment by Pacific Gas and Electric Company (the licensee) dated July 30,1997, as supplemented by letter dated December 23,1998, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's regulations set forth lii 10 CFR C hapter I; B. The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; i

C. There is reasonable assurance (i) that the activities auth;rized 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 Com nission's regulations:

D. The issuance of this amendment will not be inimical to t.1e 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.

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-80 is hereby amended to read as follows:

l 9903310324 990326 PDR ADOCK 05000275 P

PDR

i l

l l l l

(2) Technical Specifications The Technical Specifications contained in Appendix A and the Environmental Protection Plan contained in Appendix B, as revised through Amendment No.130, are hereby incorporated in the license. Pacific Gas and Electric Company shall operate the facility l

in accordance with the Technical Specifications and the Environmental Protection Plan, except where otherwise stated in specific license conditions.

I

3. This license amendment is effective as of its date of issuance to be implemerted within 30 days from the date of issuance.

FOR THE NUCLEAR REGULATORY COMMISSION

^

Steven D. Bloom, Project Manager Project Directorate IV-2 Division of Licensing Project Management Office of Nuclear Reactor Regulation

Attachment:

Changes to it.e Technical Specifications Date of issuance:

March'26, 1999 I

l

suai09 j

g>

t UNITED EYATEU g

j NUCLEAR REGULATORY COMMISSION 2

WASHINGTON, D.C. 30666-0001 l

l PACIFIC GAS AND ELECTRIC COMPANY DOCKET NO. 50-323 DIABLO CANYON NUCLEAR POWER PLANT. UNIT NO. 2 l

AMENDMENT TO FACILITY OPERATING LICENSE Amendment No.128 License No. DPR-82

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

A. The application for amendment by Pacific Gas and Electric Company (the licensee) l deted Ju!y 30,1997, as supplemented by letter dated December 23,1998, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's 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 and safety of the public, and (ii) that such activities will be conducted in compliance with the Commission's regulations; i

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 l

Commission's regulations and all applicable requirements have been satisfied.

2. Accordingly, the license is amended by changes to the Technical Specifications as indicated in the attachment to this license amendment, and paragraph 2.C.(2) of Facility Operating License No. DPR-82 is hereby amended to read as follows:

l

,e,a-a me-

(2) T_f shnical Soecifications The Technical Specifications contained in Appendix A and the Environmental Protection Plan contained in Append!x B, as revised through Amendment No.128, are hereby incorporated in the license. Pacific Gas and Electric Company shall operate the facility in accordance with the Technical Fweifications and the Environmental Protection Plan, except where otherwise stated ir, specific license confitions.

3. This license amendment is effective as of its date of issuance to be implemented within 30 days from the date of issuance.

FOR THE NUCLEAR REGULATORY COMMISSION l'

V Steven D. Bloom, Project Manager Project Directorate IV-2 Division of Licensing Project Management

, Office of Nuclear Reactor Regulation

Attachment:

Changes to the Technical Specifications Date of issuance:

March 26, 1999 1

l i

I I

l

ATTACHMENT TO LICENSE AMENDMENTS AMENDMENT NO. 130 TO FACILITY OPERATING LICENSE NO. DPR-80 AND AMENDMENT NO.128 TO FACILITY OPERATING LICENSE NO. DPR-82 DOCKET NOS. 50-275 AND 50-323 Revise Appendix A Technical Specifications by removing the pages identified below and inserting the enclosed pages. The revised pages are identified by Amendment number and contain marginallines indicating the areas of change. The corresponding overleaf pages are also provided to maintain document completeness.

REMOVE INSERT 3/4 3-20 3/4 3-20 3/4 3-22 3/4 3-22 3/4 3-27 3/4 3-27 3/4 3-35 3/4 3-35 B 3/4 3-1b B 3/4 3-1b t

e

- _. _. _. _.... _. ~ _ _

~

i TABLE 3.3-3 (Continued)

ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRIN NTATION i

W o

MINIMUM l

TOTAL NO.

CHANNELS CHANNELS APPLICABLE k" WIGIRL UNIT DE CHANNELS TO TRIP OPERABLE MODES EHg

'i i

!i!

, 6.

Auxiliary Feedwater l

I l

5 a.

Manual Initiation 1 manual 1 manual 1 manual

1. 2, 3 24 switch / pump switch / pump switch /puup i

b.

Automatic Actuation _

2 1

2 1, 2, 3 22

~

Logic and Actuation I

Relays c.

Sts. Gen. Water Level-Lou-Low l'

1)

Start Motor-Driven Pumps j

i; a.

Steam Generater 3/S.G.

2/S.G.

1, 2, 3###

20 ll

~

Water Level-in one in each i

Low-Low S.G.

S.G.

i ll;{

5 b.

RCS loop AT 4 (1/ loop)

N.A.

1, 1 29 l;

i I

33 2)

Start Turbine-Driven Pump l

- ~

8 8 3.

gy a.

Steam Graerator 3/S.G.

2/S.G.

1, 2, 3fff 20 l!

gg Water Level-in any in each l

j; gg Low-Low 2 S.G.

S.S.

r

~

Ea t

RCS loop AT 4 (1/ loop)

N.A.

1, 2 29 ll l,

m m j,'j,'

d.

Undervoltage-RCP Bus 2/ bus 1/ bus on 1/ bus 1

35 l

+

p Start Turbine-both busses w

3;;

Driven Pump j

DD e.

Safety Injection Start See Item 1. above for all Safety Injection initiating functions and j

Motor-Driven Pumps requirements.

t l

i'!

i TABLE 3.3-3 (Continued) t ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION 9-m MINIMUM i

I o

TOTAL NO.

CHANNELS CHANNELS APPLICABLE -

Q FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION z

i' o

7.

Loss of Power (4.16 kV Emergency z

Bus Undervoltage)

C

-i Z

a.

First Level 1,2,3,4 l

N

1) DneselStart 1/ Bus 1/ Bus 1/ Bus 16

^

em t

2) Inst ation of Load Shed 2/ Bus 2/ Bus 2/ Bus 15 f

b.

Second Level 1,2,3,4 g

1) Undervoltage Relays 2/ Bus 2/ Bus 2/ Bus 15 u

g

2) Timers to Start Dutsel 1/ Bus 1/ Bus 1/ Bus 16 l

3) Timers to Shed Load 1/ Bus 1/ Bus 1/ Bus 16 8.

Engineered Safety Features i

Actuation System Interlocks

{

CC EE a.

P6essunzer Pressure, P-11 3

2 2

1,2,3 21 l

w*

j b.

DELETED l

33 f

nm t

aa c.

Reactor Trip, P-4 2

2 2

1,2,3 23 i

33 i

um 1

aa 9.

Residual Heat Removal Pump 3

2 2

1,2,3,4 36 8 g Trip on Refueling Water Storage

};};

Tank Level-Low l

i CU ma l

t

TABLE 3.3e3 (Continued)

TABLE NOTATIONS

-# Trip function may be blocked in this MODE below the P-11 (Pressurizer Pressure Interlock) Setpoint.

M Trip function automatically blocked above P-11 (Pressurizer Pressure Interlock) Setpoint and is automatically blocked below P-11 when Safety Injection on Steam Line Pressure-Low is not blocked.

j

1. For Node 3. the Trip Time Delay associated with the Steam Generator Water Level-Low-Low channel must be less than or equal to 464.1 seconds.

ACTION STATEMENTS ACTION 14 - 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 and in COLD SHUTDOWN within the following 30 hour3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months s: 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

'3 for surveillance testing per Specification 4.3.2.1, provided the other channel is OPERABLE.

ACTION 15 - With the number of OPERABLE Channels less than the. Minimum Channels OPERABLE requirement. declare the affected Emergency i

Diesel Generator (s) inoperable and comply with the ACTION

)

statements of Specification 3.8.1.1: 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 4.3.2.1.

ACTION 16 - With the number of OPERABLE Channels one less than the. Total Number of Channels, declare the affected Emergency Diesel Generator (s) inoperable and comply with the ACTION statements of Specification 3.8.1.1: 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 4.3.2.1.

ACTION 17 - With the number of OPERABLE channels one less than the Total Number of Channels. operation may proceed provided the inoperable channel is ] laced in the bypassed condition and the Minimum Channels OPERABL E requirement is met. One additional channel may i

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.

ACTION 18 - With less than the Minimum Channeis OPERABLE requirement, operation may continue provided the containment purge supply and exhaust valves (RCV-11, 12. FCV 660, 661, 662. 663. 664) are maintained closed.

ACTION 19 - 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 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 .

ACTION 20 - 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 or 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.

DIABLO CANYON - UNITS 1 & 2 3/4 3-21 Unit 1 - Amendment No. 51.Sd.103.127 Unit 2 - Amendment No. 50.83.102.125

TABLE 3.3-3 (Continued)

ACTION STATEMENTS (Continued)

ACTION 21 - With less than the Minimum Number of Channels 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.

ACTION 22 -

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 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 surveillance testing per Specification 4.3.2.1 provided the other channelis OPERABLE.

ACTION 23 - 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 .

ACTION 24 - 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 pump or valve inoperable and take the ACTION required by Specification 3.7.1.5 or 3.7.1.2 as applicable.

ACTION 25 -

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 4.3.2.1 provided the other channel is OPERABLE.

ACTION 29 -

With the number of OPERABLE channels less than the Total Number of Channels, STARTUP and/or POWER OPERATION may proceed provided that within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , for the affected RCS Loop Delta-T channel (s), either:

a.

The Trip Time Delay threshold power level for :.ero seconds time delay is adjusted to 0% RTP, or b.

With the number of OPERABLE channels one less than the Total Number of Channels, the affected Steam Generator Water Level-Low-Low channels are placed in the tripped condition.

ACTION 35 - 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 channelis placed in the trip 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 4.3.2.1.

ACTION 36 - With the number of OPERABLE channels one less than the Total Number of Channels, within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months place the inoperable channel in cut-out and 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 the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and be in Cold Shutdown within the next 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

DIABLO CANYON - UNITS 1 & 2 3/4 3-22 Unit 1 - Amendment No. 01,04,103,130 Unit 2 - Amendment No. 00,00,102,128

TABLE 3.3-4 (Continued)

ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION TRIP SETPOINTS FUNCTIONAL UNIT TRIP SETPOINT-ALLOWABLE VALUES y

cn 7.

Loss of Power (4.16 kV Emergency Bus Undervoltage) o a.-

First Level o

1)

Diesel Start 2 0 volts with a 2 0 volts with a 3

s 0.8 second time delay s 0.8 second time delay

-y and and z

2 2583 volts with a 2 2583 volts with a g

s 10 second time delay s 10 second time delay z

2)

Insbebon of Load Shed One relay One relay g

2 0 volts with a 2 0 volts with a l

s 4 second time delay s 4 second time delay a

9*

and and 2 2583 volts with a 2 2583 volts with a

[

s 25 second time delay s 25 second time delay i

with one relay with one relay l

2 2870 volts, instantaneous 2 2870 volts, instantaneous b.

Second Level Y

1)

Diesel Start 2 3785 volts with a 2 3785 volts with a t$

s 10 second time delay s 19 second time delay 2)

Initiation of Load Shed 2 3785 volts with a 2 3785 volts with a l

s 20 second time delay s 20 second time delay 8.

Engineered Safety Features Actuabon l

cc RR System Interlocks 7 ";'

a.

Pressurizer Pressure, P-11 s 1915 psig s 1917.5 psig i

b.

DELETED 33 c.

Reactor Trip, P-4 N.A.

N.A.

t oo F

9.

Residual Heat Removal Pump Trip 32.56 %

s 33.68% and i

g d9 on Refueling Water Storage Tank 2 31.44 %

~C Level-Low h

j 3

a i

iOj NOTE 1:

Time constants uhlized in the lead-lag compensator for Steam Pressure - Low are T, = 50 seconds and T = 5 seconds.

2 bg NOTE 2:

Steam Generator Water Level Low-Low Trip Time Delay

{l-TD = B1(P)8 + B2(P)2 + B3(P) + B4 p

{l-j Where: P

= RCS Loop AT Equivalent to Power (%RTP), P s 50% RTP l

c'?2 TD

= Time delay for Steam Generator Water Level Low-Low (in seconds) 8 8 B1 = -0.007128 f

I

-Il B2 = +0.8099 l

j$j$

B3 = -31.40

[

B4 = +464.1

~~

$E$

NOTE 3:

Time constants utilized in the rate-lag compensator for Negative Steam Line Pressure Rate - High are T = 50 seconds and 3

T. = 50 seconds.

j

=

TABLE 1.1 1 ENSfNEERED SAFETY FEATURES RESPONSE TIMES INfffATING SfGNAL AND FUNCTION RESPONSE TIME IN SECONDS 1.

Manual Initiation a.'

Safety Injection (ECCS)

N. A..

1)l Feedwater Isolation N.A.

I Reactor Trip N.A.

3h Phase 'A' Isolation N.A.

~

4)

Containment Ventilation Isolation N.A.

5) Auxiliary Feedwater N.A.

8)1 Component Cooling' Water N.A.

7 Containment Fan Cooler Units N.A.

Sh Auxiliary Saltwater Pumps N.A.

b.

Phase '8" Isolation 1)

Containmentspray(Coincidentwith 31 Signal)

N.A.

2)

Containment Ventilation Isolation N.A.

c.

Phase 'A' Isolation 1)

Containment Ventilation Isolation N.A.

~

d.

Steam Line Isolation N.A.

1.

Containment Pressure-High a.

SafetyInjection(ECCS) s 17*/25*

11 Reactor Trip s2 2'l Feedwater Isolation s 43 l

)l Phase 'A' Isolation s 18"'/28

3 4

Containment Ventilation Isolation Eh Auxiliary Feedwater N.A.

s 60 51 Component Cooling Water s 38'p48*

71 Containment Fan Cooler Units s 40 sh Auxiliary Saltwater Pumps s 48"'/58 "

3.

Pressurizer Pressure Low a.

Safetyinjection(ECCS)

' s 17m/25*/35*

11 Reactor Trip s2 2h Feedwater Inslation s 43

[

31 Phase 'A' Isolation s 18"8

)'

4 l Containment Ventilation Isolation N.A.

5 Auxiliary Feedwater s 60 E l Component Cooling Water s 48g38"'

71 Containment Pan Cooler Units s 40 Sjl Auxiliary saltwater Pumps s $8 /48"'

8 DIABLO CANYON - UNITS 1 & 2 3/4328 Amendment Nos. 46146, M & M, 77 & 76 4Ph' veW i 6'@ y $N1 a,

m.m=adm e

ue6**

e-

TABLE 4.3-2 (Continued)

O 5

ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION 6

SURVEILLANCE REQUIREMENTS Og TRIP ACTUATING CHANNEL DEVICE MODES FOR CHANNEL OPERA-OPERA-MASTER SLAVE WHICH E

CHANNEL Call-TIONAL TIONAL ACTUATION RELAY RELAY SURVEILLANCE 9 FUNCTIONAL UNIT CHECK BRATION TEST TEST LOGICTEST TEST TEST IS REQUIRED us

' 6. Auxiliary Feedwater (Continued) d.

Undervoltage - RCP NA R24 NA R24 NA NA NA 1

e.

Safety injection See item 1. above for all Safety injection Surveillance Requirements.

7. Loss of Power

a. 4.16 kV Emergency Bus NA R

NA R

NA NA NA 1,2,3,4 wI Level 1 y

b. 4.16 kV Emergericy Bus NA R

NA R

NA NA

' NA 1,2,3,4 I

m Level 2

8. Engineered Safety Feature ec g3 Actuation System Interlocks Y~'

a. Pressurizer Pressure, NA R24 Q

NA NA NA NA 1,2,3 gg P-11 t

mo

b. Deleted EE

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

NA NA R24 NA NA NA 1,2,3 BB l

ue RR 9. Residual Heat Removal Pump S

R24 Q

N.A.

R24 NA NA 1,2,3,4

_8$2 Trip on Refueling Water Storage 8 H Tank Level-Low l

1312

'o-4 TABLE NOTATIONS l

E,$ 8

]

i:l: W Each train shall be tested at least every 62 days on a STAGGERED TEST BASIS.

[

I 3 r23 For the Containment Ventilation Exhaust Radiation-High monitor only, a CHANNEL FUNCTIONAL TEST shall be performed at least f2 once every 31 days.

i

};};*

Trip function automatically blocked above P-11 (Pressurizer Pressure interlock) setpoint and is automatically blocked below P-11 when l

Safety injection on Steam Line Pressure-Low is not blocked.

5)Sa ilil "3 Deleted.

l O-O

For Mode 3, the Trip Time Delay associated with the Steam Generator Water Level-Low-Low channel must be less than or equal to E}$

464.1 seconds.

,t

ra s anto All0N 3/4. 3. 3 DONITORING INSTRUMENTATION e

RAD 1& TION MNITORING FOR ptAWT OPERATIONS 114171N3 CONDIT10N FOR OPERATION 3.3.3.1 The radiation monitoring instrumentation channels for plant operattens shown in Table 3.3 8 shall be 071AABLE with their Alars/ Trip Setpoints within tAe specified Itaits.

A'#LfC431L7TY: As shown in Table 3.9-8.

.ams With a radiation monitoring thannel Alors/ Trip Setpoint for plant s.

operations exceeding the value shown in Table 3.3 5, adjust the Setpoint to within the 11af t within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months er declare the thannel (noperable.

6.

With one or more radiation sonitoring channels for plant operattens inoperable, take the ACTION shown in Table 3.3 8.

The provisions of specification 3.0.3 are not applicable.

l s.

SVevf1LLANCE tt001RIMtWTS 4 3.31 Yt:6. radiatten monitoring instrumentation thannel for plant operations shall be der.anstrates CPIRAllt by the perforsence of the CHANNEL CHICK CAL 18 TAT 30N and CHANNEL FUNCTIONAL TEST for the MODES and at the freque CM ncies shown la Table 4.3 3.

SIASLD EAWYDN = UNITS 1 & 3 3/4 3 3s Amendment Nos. 55 and 54 1

-==enme.w--

-Y" TWTT P 7#%% +p ve.*iw v 97.r p t'Mo '

rp-t-*9*'*,W'-?"

r

INSTRUMENTATION BASES REACTOR PROTECTION SYSTEM and ENGINEERED SAFETY FEATURES ACTUATION j

SYSTEM INSTRUMENTATION (Continued)

ESF response times specified in Table 3.3-5, which include sequential operation of the RWST and VCT valves (Table Notations 4 and 5), are based on values assumed in the non-LOCA safety analyses. These analyses take credit for injection of borated water from the RWST. Injection of borated water is assumed not to occur until the VCT charging pump suction Isolation valves are closed following opening of the RWST charging pump suction isolation valves. When the sequential operation of the RWST and VCT valves is not included in the response times (Table Notation 7), the values specified are based on the LOCA analyses. The LOCA analyses takes credit for injection flow regardless of the source. Verification of the response times specified in Table 3.3-5 will assure that the assumptions used for the LOCA and non-LOCA analyses with respect to the operation of the VCT and RWST valves are valid.

For slave relays in the ESF actuation system circuit that are Potter & Brumfield type MDR relays, the SLAVE RELAY TEST is performed on a refueling frequency. The test frequency is based on relay reliability assessments presented in WCAP-13878, " Reliability Assessment of Potter and Brumfield MDR Series Relays," WCAP-C," Extension of Slave Relay Surveillance Test Intervals," and WCAP-14117, "Rehability Assessment of Potter and Brurdield MDR Series Relays." These reliability assessments are relay specific and apply only to Potter and Brumfield MDR series relays. Note that for normally energized applications, the relays may have to be replaced periodically in accordance with the guidance given in WCAP-13878 for MDR relays.

Undervoltage protection will generate a loss of power diesel generator start in the event a loss of voltage or degraded voltage condition occurs. The diesel generators provide a source of emergency power when offsite power is either unavailable or is insufficiently stable to allow safe unit operation. The first level undervoltage relays (FLURs) detect the loss of bus voltage J

(less than 69% bus voltage). The second level undervoltage relays (SLURS) provide a second level of undervoltage protection which protects all Class 1E loads from short or long term degradation in the offsite power system. The SLUR allowable value is the minimum steady state voltage needed on the 4160 volt vital bus to ensure adequate voltage is available for safety related equipment at the 4160 volt,480 volt, and 120 volt levels.

The RWST low level trip of the RHR pumps, the only automatic action in the switchover to the containment recirculation sump, asse es that continued cooling is provided by the ECCS to remove decay heat. After the RWST low level trip is received, operators manually switch the source of water for the ECCS pumps to the containment recirculation sump. Switchover from the RWST to the containment sump must occur before the RWST empties to prevent damage to the ECCS pumps and a loss of core cooling capability. For similar reasons, switchover must not occur before there is sufficient water in the containment sump to support RHR pump suction. Furthermore, early switchover must not occur to ensure that sufficient borated water is injected from the RWST. This ensures the reactor remains shut down in the recirculation mode.

The RWST low level trip of the RHR pumps is included in the RHR pump control system and is not a part of the solid state protection system. Each of the three channels is provided with a cut-out feature, which allows the channel to be bypassed. A channel may be placed in the cut-out mode for up to 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months to allow maintenance and testing. This places the system in a two-out-of-two trip logic.

DIABLO CANYON - UNITS 1 & 2 B 3/4 3-1b Unit 1 - Amendment No. 115,122,130 Unit 2 - Amendment No. 113,120,128

._

ML20205B670

Text

Attachment:

Attachment:

Navigation menu

Search