Text

Amends 114 & 112 to Licenses DPR-80 & DPR-82,respectively, Revising TS 3/4.3.2 & 3/4.6.2 to Clarify Description of Initiation Signal Required for Operation of Containment Spray Sys at Plant
	ML20116J446
Person / Time
Site:	Diablo Canyon
Issue date:	08/01/1996
From:	Steven Bloom; NRC (Affiliation Not Assigned)
To:	;
Shared Package
ML20116J447	List: ML20116J446; ML20116J452;
References
	NUDOCS 9608130207
	Download: ML20116J446 (17)
	v • d • e

_ _______

pa orog 4

UNITED STATES j

^

NUCLEAR REGULATORY COMMISSION l

f WASHINGTON, D.C. 20665 4 001

%...../

PACIFIC GAS AND ELECTRIC COMPANY DOCKET NO. 50-2Z1 DIABLO CANYON NUCLEAR POWER PLANT. UNIT NO. 1 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No. 114 License No. DPR-80 1.

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

A.

The application for amendment by Pacific Gas and Electric Company (the licensee) dated May 9, 1996, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Comission'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 Comission; C.

There is reasonable assurance (1) 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 Comission'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.

2.

Accordingly, the license is amended by changes to the Technical Specifications as indicated in the attachr. ant to this license amendment, and paragraph 2.C.(2) of Facility Operating License No. DPR-80 is hereby amended to read as follows:

9608130207 960801 DR ADOCK 0500 5

h b Y h ?h Y $

. (t)

Technical Snecifications i

The Technical Specifications contained in Appendix A and the Environmental Protection Plan contained in Appendix B, as revised through Amendment No.114, are hereby incorporated in the license.

Pacific Gas and Electric Company shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan, except where otherwise stated in specific license conditions.

3.

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

FOR THE NUCLEAR REGULATORY COPMISSION 1

l,

'G -

,5tevenD. Bloom,ProjectManager Project Directorate IV-2 Division of Reactor Projects III/IV Office of Nuclear Reactor Regulation

Attachment:

Changes to the Technical Specifications Date of Issuance:

August 1, 1996 I

pf.Rtc 24 UNITED STATES y-NUCLEAR REGULATORY COMMISSION If WASHINGTON, D.C. 20066-0001

\\...../

PACIFIC GAS AND ELECTRIC COMPANY DOCKET NO 50-323 DIABLO CANYON NUCLEAR POWER PLANT. UNIT NO. 2 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No. 112 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) dated May 9, 1996, 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 (1) 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, 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:

d (2)

Technical Soecifications The Technical Specifications contained in Appendix A and the Environmental Protection Plan contained in Appendix B, as revised through Amendment No.112, are hereby incc.rporated in the license. Pacific Gas and Electric Company shall operate the facility in accordance with the Technical Specifications and the

{

Environmental Protection Plan, except where otherwise stated in specific license conditions.

3.

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

FOR THE NUCLEAR REGULATORY COMISSION

/

De

. Steven D. Bloom, Project Manager Project Directorate IV-2 Division of Reactor Projects III/IV Office of Nuclear Reactor Regulation

Attachment:

Changes to the Technical Specifications Date of Issuance:

August 1, 1996

ATTACHMENT TO LICENSE AMENDMENTS AMENDMENT NO.114 TO FACILITY OPERATING LICENSE NO. DPR-80 AND AMENDMENT NO. 112 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 marginal lines indicating the areas of change.

The corresponding overleaf pages are also provided to maintain document completeness.

REMOVE INSERT 3/4 3-16 3/4 3-16 3/4 3-24 3/4 3-24 3/4 3-32 3/4 3-32 3/4 3-34 3/4 3-34 3/4 3-35 3/4 3-35 3/4 6-11 3/4 6-11 l

1 o

TABLE 3.3-3 o

g ENr.imiRtn sat ty_r_tafunts_acilMT_ ION _5ritiM INSTMMENTATION l

5 MINIM M "h

TOTAL NO.

CHANNils CWNR LS APPLICABLE FINCTIONAL_1981T Or_C:lANNIl.5 10.IRIP_

OPIRABtE MODES ACTION a

i 1.

Safety In.lection (Reactor g

Trip. Feedseter Isolation.

Start Dies 21 Generators.

~

l Cl Containment Fan Cooler Units.

l and Component CJoling Water) e.

=

a.

Manuel Initiation 2

1 2

1. 2. 3. 4 19 i

b.

Automatic Actuation 2

1 2

1. 2. 3. 4 14 Logic and Actuation IIelays s

c.

Containment 3

2 2

1.2.3.4 20 g

Pressure High d.

Prn:wimr 4

2 3

1. 2. 3f 20 Pressue? Low u

e.

DELETED l

f.

Steen Line Pressure law 3/ steam line 2/ steam Ifne 2/stese Ifne

1. 2. 39 20 in any steam line a

Er D

1 1

l TABLE 3.3-3 (Continued)

ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION s

n MINIMUM g

TOTAL N0.

CHANNELS CHANNELS APPLICA8LE FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION g

2.

Containment Spray (coincident l

E with SI signal)

U a.

Manual 2

2 with 2 2

1, 2, 3, 4 19

~

coincident switches m

b.

Automatic Actuation 2

1 2

1, 2, 3, 4 14 Logic and Actuation Relays c.

Containment Pressure-4 2

3 1, 2, 3, 4 17 High-High w

3.

Containment Isolation a.

Phase "A" Isolation 1)

Manual 2

1 2

1, 2, 3, 4 19 2)

Automatic Actuation 2

1 2

1, 2, 3, 4 14 Logic and Actuation m-Relays kk 3)

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

b.

Phase "B" Isolation ks 1)

Manual 2

2 with 2 2

1,2,3,4 19 coincident

.E.I switches 20 ma

__m.--mm_.,___.2

________m.___

__.-:--_.=_m._.-__ma____-_-m__

_____-__.___-m__

_.-_m_

TABLE 3.3 4 e

{

g ENGINEERED SAFETY FEAilRES ACTUATION SYSTEM INSTRUMENTATION TRIP SETPOINTS I

b FUNCTIONAL LMIT TRIP SE.TPOINT ALLOWABLE VALUES

]

1.

Safety injection (Reactor Trip. Feedwate:'

R Isolation Start Diesel Generators,

~

h Containment Fan Cooler Units, and g

Component Cooling Water) 4 C!

a.

Manual Initiation N.A.

N.A Tc e-b.

Automatic Actuation Logic N.A.

N.A and Actuation Relays ru c.

Containment Pressure High s 3 psig s 3.3 psig l

h d.

Pressurizer Pressure Low e 1850 psig e 1844.4 psig e.

DELETED l

e w

g 2

f.

Steam Line Pressure Low e 600 psig (Note 1)

= 594.6 psig (Note 1) l a

w w

w n

g h

y

+

k 8

?

s a

l 5

g r

Ett e

4

TABLE 3.3-4 (Continued)

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

2.

Containment Spray (coincident I

with SI signal) o 7

a.

Manual Initiation N.A.

M.A E

b.

Automatic Actuation Logic and N.A.

N.A

]

Actuation Relays

~

c.

Containment Pressure-High-High s 22 psig s 22.3 psig 3.

Containment Isolation a.

Phase "A" Isolation g

1)

Manual N.A.

N.A 2)

Automatic Actuation Logic N.A.

M.A.

w k

and Actuation Relays 3)

Safety Injection See Item 1. above for all Safety Injection Trip Setpoints and Allowable Values.

b.

Phase "B" Isolation ee

==

?3 1)

Manual N.A.

N.A

~~

2)

Automatic Actuation Logic N.A.

M.A i i gg and Actuation Relays em EE 3)

Containment Pressure-High-High s 22 psig s 22.3 psig RR aa E.E

~n m___m

l Tamar 3.3 5 fconti M DBLENDTATIGIS (1) Diesel generator starting delay not included because offsite power available.

(2) Notation deleted.

l (3) Diesel generator starting and loading delays included.

(4) Diesel generator starting delay not included because offsite gouer is available.

Response time limit includes opening of valves to establish SI h and attairusent of discharge pressure for centrifuge 1 charging puups (idiere 1 cable). Sogaen-tial transfer of charging pump suction from the VET to the (Ed5T valves apen, then VCT valves close) is included.

(5) Diesel generator starting and sequence loading delays included. Offsite poner is not available. Response time limit includes opening of valves to establish $1 path and attainment of discharge pressure for centrifuge 1 chargi Sequential transfer of charging pump suction from the VCT to the Rd5T (

valves open, then VCT valves close) is included.

(6) The maximum response time of 4f. 5 '

onds is the time from uhen the containeent pressure exceeds the High High M. -int until the spray pump is started and the discharge valve travels to the fully open position assuming off site power is not available.

The time of 48.5 seconds includes the 20 second maxima delay related to ESF loading sequence. Spray riser piping fill time is not included. The 80-second maximum spray delay time does not include the time from LOCA start to *P' signal.

(7) Diesel generator starting and sequence loading delays included. Sequential trans-fer of chargin valves close) g pump suction from the VCT to the RW$T (RW5T valves open, then VCT is tot included. Response time limit includes opening of valves to establish SI flow path and attainment of discharge pressure for centrifugal charging pumps. 51, and RHP. pumps (where applicable).

(8) Does not include Trip Time Delays. Response times include the transmitters. Eagle-21 Process Protection cabinets. Solid State Protection Systas cabinets and actua-tien devices only. This reflects the response times necessary for TERMAL POWER in excess of 502 RTP.

f DIABLO CANYON LMITS 1 & 2 3/4 3 31 Amendment Nos. 30 8 60. E & N, 84883

TABLE 4.3-2 ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION 3

SURVEILLANCE REQUIREMENTS w.

E TRIP ACTUATING j

CHANNEL DEVICE MODES FOR l

CHANNEL OPERA-OPERA-MASTER SLAVE WHICH E

CHANNEL CALI-TIONAL TIONAL ACTUATION RELAY RELAY SURVEILLANCE i FUNCTIONAL UNIT GECX__

BRATION TEST TEST LOGIC TEST TEST TEST IS REQUIRED C

5 1. Safety Injection, (Reactor Trip d

Feedwater Isolation, Start Diesel Generators, Containment Fan Cooler Units, and Component e.

Cooling Water) m a.

Manual Initiation N.A.

N.A.

R N.A.

N.A.

1, 2, 3, 4 b.

Automatic Actuation N.A.

N.A.

M(1)

Q(4) 1, 2, 3, 4 l

Logic and Actuation Relays 1

c.

Containment Pressure-High S

R Q

N.A.

1, 2, 3, 4 d.

Pressurizer Pressure-Low S

R Q

N.A N.A.

N.A.

1, 2, 3 e.

DELETED f.

Steam Line S

R Q

N.A.

1, 2, 3 Pressure-Low 772.ContainmentSpray(coincident with SI signal) l a.

Manual Initiation N.A.

N.A.

M.A.

R N.A.

M.A.

N.A.

1, 2, 3, 4 aaRR b.

Automatic Actuation Lcgic N.A.

N.A.

M(1)

Q 1, 2, 3, 4 5%

and Actuation Relays

==

PP c.

Containment Pressure-S R

Q N.A.

M.A.

N.A.

1, 2, 3, 4 g

High-High h e?

.8

~u

f TABLE 4.a-2 (Continued)

ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION o

SURVEILLANCE REQUIREMENTS 2-E TRIP ACTUATING i

y CHANNEL DEVICE MODES FOR CHANNEL OPERA-OPERA-NASTER SLAVE WHICH E

CHANNEL CALI-TIONAL TIONAL ACTUATION RELAY RELAY SURVEILLANCE i FUNCTIONAL UNIT CHECK BRATION TEST TEST LOGIC TEST TEST JISI._

IS REQUIRED c

5 3. Containment Isolation

.d a.

Phase "A" Isolation

~1) Manual N.A.

N.A.

R N.A.

N.A.

M.A.

1, 2, 3, 4

2) Automatic Actuation N.A.

N.A.

M.A.

N.A.

M(1)

Q(4) 1, 2, 3, 4 m.

Logic and Actuation m

Relays

3) Safety Injection See Item 1. above for all Safety Injection Surveillance Requirments.

w1 b.

Phase "B" Isolation

1) Manual N.A.

N.A.

R N.A.

N.A.

1, 2, 3, 4 w

de

2) Automatic Actuation N.A.

N.A.

M(1)

Q 1, 2, 3, 4 Logic and Actuation ec Relays 11

3) Containment S

R Q

N.A.

1, 2, 3, 4 Pressure-High-High

"~

c.

Containment Ventilation Isolation

((

1) Automatic Actuation N.A.

N.A.

M(1)

Q 1, 2, 3, 4 Logic and Actuation

=s&&

Relays EE

2) Deleted l

3) Safety Injection See Item 1. above for all Safety Injection Surveillance Requirements.

EE

4) Containment Ventilation Exhaust Radiation-High jS,$

(RM-44A and 448)

S R

Q N.A.

N.A.

1, 2, 3, 4 l 393h

s;;

P l

EE

~w

TABLE 4.3-2 (Continued)

ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRIMENTATION SURVEILLANCE REQUIREMENTS o

h TRIP ACTUATING CHANNEL DEVICE MODES FOR l

k CHANNEL OPERA-OPERA-MASTER SLAVE WHICH E

CHANNEL CALI-TIONAL TIONAL ACTUATION RELAY RELAY SURVEILLANCE FUNCTIONAL UNIT CHECK BRATION TEST TEST LOGIC TEST TEST TEST IS REOUIRED i

!4.SteamLineIsolation a.

Manual N.A.

N.A.

R N.A.

N.A.

M.A.

1, 2, 3 b.

Automatic Actuation Logic N.A.

N.A.

N"'

M"'

Q 1, 2, 3

~

[

2nd Actuation Relays c.

Containment Pressure-S R

Q N.A.

N.A.

1, 2, 3 High-High d.

Steam Line Pressure-Low S

R Q

N.A.

M.A.

1, 2, 3 e.

Negative Steam Line S

R Q

N.A.

M.A.

3(3)

{

Pressure Rate-High

5. Turbine Trip and Feedwater w

4, Isolation

^

a.

Automatic Actuation N.A.

N.A.

N. A..

gu gu Q

1, 2 Logic and Actuation Relays ccaa b.

Steam Generator Water S

R Q

N.A.

1, 2 Level-High-High i

~~

6. Auxiliary Feedwater i i a.

Manual N.A..

N.A.

R N.A.

M.A.

N.A.

1, 2, 3

a. o.

l 55 b.

Automatic Actuation N.A.

N.A.

Q 1, 2, 3 ER Logic and Actuation Relays EE c.

Steam Generator Water Level-Low-Low SC

1) Steam Generator S

R Q

N.A.

1, 2, 3")

h-,

j?

Water Level-Low-Low j!j!

2) RCS Loop AT N.A.

R Q

N.A.

1, 2 20

~#

TABLE 4.3-2 (Continued)

ENGINEERED SAFETY FEATURES ACTUATION SYSTEN INSTRtMENTATION SURVEILLANCE REQUIRENENTS S

B TRIP 5

ACTUATING n

CHANNEL DEVICE NODES FOR l

R CHANNEL OPERA-OPERA-MASTER SLAVE WHICH CHANNEL Call-TIONAL TTONAL ACTUATION RELAY RELAY SURVEILLANCE FUNCTIONAL UNIT GECK BRATION TEST TEST LOGIC TEST TEST TEST IS REQUIRED E 6. Auxiliary Feedwater (Continued) 3

{_

d.

Undervoltage - RCP N.A.

R N.A.

N.A.

1 I

[

e.

Safety Injection See Item 1. above for all Safety injection Surveillance Requirements.

7.

Loss of Power a.

4.16 kV Emergency Bus N.A.

R N.A.

M.A.

N.A.

1, 2, 3, 4 Level 1

{

b.

4.16 kV Emergency Bus N.A.

R N.A.

N.A.

1, 2, 3, 4 level 2 m

b8.EngineeredSafetyFeature Actuation System Interlocks cc a.

Pressurizer Pressure, N.A.

R Q

N.A.

M.A.

1, 2, 3 P-Il i e gg b.

Deleted

..gg c.

Reactor Trip, P-4 N.A.

N.A.

R N.A.

N.A.

1, 2, 3 TABLE NOTATIONS E E

")

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

3 2 (*)

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

1,1,

?? "' Trip function automatically blocked above P-II (Pressurizer Pressure Interlock) setpoint and is automatically 3!*,

blocked below P-Il when Safety Injection on Steam Line Pressure-Low is not blocked.

Except relays K612A, K6148, K615A, and K6158, which shall be tested, at a minimum, once per 18 months during 33 refueling and during each Cold Shutdown unless they have been tested within the previous 92 days.

w

") ~ For Mode 3, the Trip Time Delay associated with the Steam Generator Water Level-Low-Low channel must be less than CZ or equal to 464.1 seconds.

INSTRUMENTATION 3/4. 3. 3 MONITORINC_ INSTRUMENTATION

_ RADIATION E NITORING FOR PLANT OPE MTIONS LIMITINO CONDITION FOR OPE U TION 3.3.3.1 The radiation monitoring instrumentation channels for plant operations shown in Table 3.5-6 shall be CP1MBLE with their Alara/ Trip 5etpoints within the specified limits.

APPLICABILITY: As shown in Table 3.5-6.

ACTION:

I With a radiation monitoring channel Alarm / Trip setpoint for plant a.

operations exceeding the value shown in Table 3.3-6, adjust the Setpoint to within the 1 fait within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months or declare the channel inoperable.

b.

With one or more radiation monitoring channels for plant operations inoperable, take the ACTION shown in Table 3.3-6.

The provisions of Specification 3.0.3 are not applicabla.

l a.

SURVIILLANCE REQUIREMENTS l

4.3.3 1 Tech radiation monitoring instrumentation channel for plant operations shall be demonstrated OPERABLE by the performance of the CHANNEL CHECK, CHANNEL i

CALIBUTION and CHANNEL FUNCTIONAL TEST for the MODES and at the frequencies shown in Table 4.3-3.

DIABLD IANYON - UNITS 1 & 2 3/4 3-36 Amendment Nos. 55 and 54

O e

CONTAIMENT SYSTEMS 3/4.6.2 DEPRESSURIZATION AND COOLING SYSTEMS CONTAIMENT SPRAY SYSTEM LIMITING CONDITION FOR OPERATION 3.6.2.1 Two Containment Spray Systems shall be OPERABLE with each Spray System capable of taking suction from the RWST and transferring spray function to a RHR System taking suction from the containment sump.

APPLICABILITY: MODES 1, 2, 3 and 4.

ACTION:

With one Containment Spray System inoperable, restore the inoperable Spray System to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; restore the inoperable Spray System to OPERABLE status within the next 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

SURVEILLANCE REQUIREMENTS 4.6.2.1 Each Containment Spray System shall be demonstrated OPERABLE:

a.

At least once per 31 days by verifying that each valve (manual, power operated or automatic) in the flow path that is not locked, sealed, or otherwise secured in position, is in its correct position; b.

By verifying that on recirculation flow, each pump develops a differential pressure of greater than or equal to 205 psid when tested pursuant to Specification 4.0.5; c.

At least once per 18 months by:

1)

Verifying that each automatic valve in the flow path actuates to its correct position on an actual or simulated actuation signal, I

and 2)

Verifying that each spray pump starts automatically on an actual i

or simulated actuation signal.

i d.

At least once per 10 years by performing an air or smoke flow test through each spray header and verifying each spray nozzle is unobstructed.

I DIABLO CANYON - UNITS 1 & 2 3/4 6-11 Unit 1 - Amendment No. M,114 Unit 2 - Amendment No. W,112 l

CONTAINMENT SYSTEMS SPRAY ADDITIVE SYSTEM 1

LIMITING CONDITION FOR OPERATION 3.6.2.2 The Spray Additive System shall be OPERA 8LE with:

a.

A spray additive tank with a contained volume of between 2025 and 4000 gallons of between 30 and 32% by weight Na0H solution, and b.

Two spray additive eductors each capable of adding Na0H solution from the chemical additive tank to a Containment Spray System pump flow.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTION:

With the Spray Additive System inoperable, restore the system to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; restore the Spray Additive System to OPERABLE status within the next 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

SURVEILLANCE REQUIREMENTS 4.6.2.2 The Spray Additive System shall be demonstrated OPERABLE:

a.

At least once per 31 days by verifying that each valve (manual, power-operated, or automatic) in the flow path that is not locked, sealed, or otherwise secured in position, is in its correct position; b.

At least once per 6 months by:

1)

Verifying the contained solution volume in the tank, and 2)

Verifying the concentration of the NaOH solution by chemical analysis.

c.

At least once per 18 months by verifying that each automatic valve in the flow path actuates to its correct position on a Containment Spray actuation test signal; and d.

At least once per 5 years by verifying both spray additive and RWST i

full flow from the test valve 8993 in the Spray Additive System.

DIABLO CANYON - UNITS 1 & 2 3/4 6-12

->

ML20116J446

Text

Attachment:

Attachment:

Navigation menu

Search