Text

Amend 19 to License NPF-4,deleting Verification of Tech Spec Trip Setpoint Values for Reactor Protection Sys & Engineered Safety Features Sys,& Revising Tech Specs for Operability of Safety Sys & ECCS Requirements
	ML19331C286
Person / Time
Site:	North Anna
Issue date:	08/05/1980
From:	Clark R; Office of Nuclear Reactor Regulation
To:	;
Shared Package
ML19331C284	List: ML19331C283; ML19331C286; ML19331C291; ML19331C301;
References
	NUDOCS 8008140504
	Download: ML19331C286 (44)
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i O

i VIRGINIA ELECTRIC POWER COMPANY DOCKET NO. 50-338 NORTH ANNA POWER STATION, UNIT NO. 1 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No.19 License No. NPF-4 1.

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

A.

The applications for amendment 'oy the Virginia Electric ar.d Power Company (the licensee) dated September 28, October 13, and December 12, 1978, December 28, 1979, February 25, March 31, May 16, June 2, and July 3,1980, cogly with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act) and the Comission'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 Comission; 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 cogliance with the Comission's regulations; D.

The issuance of this amendment will not be inimical to the comon 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 Comission's regulations and all applicable requirements have been satisfied.

,8008140 g y l

~~

h 2-i I

I t

2.

Accordingly. the license is amended by changes to the Technical Specifications as indicated in the attachment to this license amendment, and paragraph 2.D.(2) of Facility Operating License No. NPF-4 is hereby amended to read as follows:

2.0.(2) _ Technical Specifications The Technical Specifications contained in Appendices A and B, as revised through Amendment No.19, are hereby incorporated in the license. The licensee shall operate the facility in accordance with the Technical Specifications.

3.

Further, the following paragraph of Facility Operating License No. NPF-4 is hereby deleted.

Paragraph 2.0. (3).g 4.

Also, new paragraph 2.0.(3).0, as issued in Amendment No.16 to Facility Operating License No. NPF-4, is hereby corrected to read:

Paragraph 2.0. (3).r.

5.

The license amendment is effectiv'e as of the date of issuance.

FOR THE NUCLEAR REGULATORY COMMISSION t

obert A. Clark, Chief Operating Reactors Branch #3 Division of Licensing

Attachment:

Changes to the Technical Specifications Date of Issuance: August 5,1980 r

l g

m -

i ATTACHMENT TO LICENSE AMENDMENT NO.19 i

1 FACILITY OPERATING LICENSE NO. NPF-4 I

l DOCKET NO. 50-338 Replace the following pages of the Appendix "A" Technical Specifications i

with the enclosed pages as indicated. The revised pages are identified by Amendment number and contain vertical lines indicating the area of change. The corresponding overleaf pages are also provided to maintain document completeness.

Paces 2-7 2-10 3/4 0-1 3/4 0-2 3/4 0-3 3/4 3-24 3/4 3-25 3/4 3-26 3/4 3-26a 3/4 5-5 3/4 7-5 3/4 7-6 3/4 7-32 e

3/4 7-33 3/4 7-36 3/4 7-54 3/4 7-61 3/4 7-63 3/4 7-65a 3/4 7-65b (added)

B 3/4 0-1 B 3/4 0-2 B 3/4 0-3 B 3/4 0-4 (added) 6-1 6-4 6-4a (added)

i TABLE 2.2-1 (Continued)

Ei

\\

'~

25 REACTOR TRIP SYSTEM INSTRUMENTATION TRIP SETPOINTS x

3; FUNCTIONAL UNIT TRIP SETPOINT ALLOWABLE VALUES j

z ll

13. Steam Generator Water

> 18% of narrow range instrument

> 17% of narrow range instrument l sj Level--Low-Low span-each steam generator span-each steam generator

14. Steam /Feedwater Flow

< 40% of full steam flow at

< 42.5% of full steam flow at Mismatch and Low Steam RATED THERMAL POWER coincident RATED THERMAL POWER coincident Generator Water Level with steam generator water level with steam generator water level

> 25% of narrow range instru-

> 24% of narrow range instru-ment span--each steam generator ment span--each steam generator

15. Undervoltage-Reactor

> 2905 volts-each bus

> 2870 volts-each bus 1

Coolant Pump Busses i

16. Underfrequency-Reactor

> 56.1 Hz - each bus

> 56.0 Hz - each bus m

4.

Coolant Pump Busses

17. Turbine Trip

~

A.

Low Trip System

> 45 psig

> 40 psig Pressure B.

Turbine Stop Valve

> 1% open

> 0% open Closure

18. Safety Injection Input Not Applicable Not Applicable from ESF h*

19. Reactor Coolant Pump

!lot Applicable Not Applicable jt Breaker Position Trip a

E

- - _.,.. :i

a g

TABLE 2.2-1 (Continued) 5 i

2 REACTOR TRIP SYSTEM INSTRUMENTATION TRIP SETPOINTS 3;

3E NOTATION

,1

1 -(T-T')+K(P-P')-f(AI)]

NOTE 1:

Overtemperature AT < ATg [K -K2 3

j

]

j

,1 +'2 <3 where:

AT, Indicated AT at RATED THERMAL POWER

=

Average temperature. *F T

.=

Indicated T at RATED THERHAL POWER < 580.3*F T'

=

avg Pressurizer pressure, psig P

=

2235 psig (indicated RCS nominal operating pressure)

'?

P'

=

1+tjS j

3=

The function generated by the lead-lag controller for T,yg dynamic compensation tj & '2 = Time constants utilized in the lead-lag controller for Tavg 'l =

secs, 2 = 4 secs..

1 I

S Laplace transform operator

=

w u

m

TABLE 2.2-1 (Continued) 2g y

REACTO.< TRIP SYSTEM INSTRUMENTATION TRIP SETPOINTS h

NOTATION (Continued)

Y Operation with 2 Loops Oper ation with 2 Loops E

Operation with 3 Loops q

(no loops isolated)*

(1 loop isilated)*

(

')

(

)

K, 1.141 K

K

=

j j

j I

I I

I K

0.0128 K

K

=

2 2

2

(

)

(

)

K 0.000608 K

K

=

3 3

3 and fi (al) is a function cf the indicated difference between top and bottom detectors of the power-range nuclear ion chambers; with gains to be selected based on measured instrument response during plant startup tests such that:

- qh between - 34 percent and + 10 percent, fi (AI) = 0 (i) forq$q (wher and q are percent RATED THERMAL POWER in the top and bottom halves of the chre respectively, and qt

9 is total THERMAL POWER in b

percent of RATED THERMAL POWER).

for each percent that the magnitude of (q

-q exceeds - 34 percent, the AT trip setpoint shall be automaticalfy rebu)ced by 2 percent of (ii) its value at RATED THERMAL POWER.

h" the AT trip setpoint shall be automaticalfy rebu)ced by 1.25 percent of (iii) for each percent that the magnitude of (q

-q exceeds + 10 percent, its value at RATED THERMAL POWER.

E E

Values dependent on NRC approval of ECCS evaluation for these operating conditions.

. Am

- - n :,.

,1

a y

TABLE 2.2-1 (Continued)

-4 REACTOR TRIP SYSTEM INSTRUMENTATION TRIP SETPOINTS

=

?

NOTATION (Continued)

E-S

'3

~

T-K6(T-T")-fIAI)3 2

Note 2:

Overpower AT 1 AT [K -K5 1+t S 2

g 4 3,

Indicated AT at rated power where:

AT

=

g Average' temperature. *F T

=

Indicated T at RATED THERMAL POWER 1 580.3 F T"

=

avg h

K 1.086

=

4 0.02/*F for increasing average temperature K

=

S 0 for decreasing average temperatures K

=

5 0.00116 for T > T"; K6 = 0 for T 1" T

K

=

6 S

'3 The function generated by the rate lag controller for T,yg

=

1+r S 3

dynamic compensation Time constant utilized in the rate lag controller for T,yg

)~

3 1

=

1 = 10 secs.

l g

3 j

n Laplace transform operator S

=

f f (a!) =

0 for all AI o

2 Note 3:

The channel's maximum trip point shall not exceed its computed trip point by more than l

2 percent span.

1

___,,,a 4

N----

3/4 LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REOUIREMENTS 3/4.0 APPLICABILITY LIMITING CONDITION FOR OPERATION d

3.0.1 Limiting Conditions for Operation and ACTION requirements shall be applicable during the OPERATIONAL MODES or other conditions specified for each specification.

3.0.2 Adherence to the requirements of the Limitina Condition for Oceration and/or associated ACTION within the specified time interval shall constitute compliance with the specification.

In the event the Limiting Condition for Operation is restored prior to expiration of the specified time interval, comoletion of the ACTION statement is not required.

3.0.3 In the event a Limiting Condition for Operation and/or associated ACTION requirements cannot be satisfied because of circumstances in excess of those addressed in the scecification, the unit shall be placed in at least HOT STANDBY within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months , in at least HOT SHUTDOWN within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and in at least COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months unless corrective measures are completed that permit operation under the permissible ACTION statements for the specified time interval as measured from initial discovery or until the reactor is placed in a MODE in which the specification is not applicable. Exceptions to these requirements shall be stated in the individual specifications.

3.0.4 Entry into an OPERATIONAL MODE or other specified applicability condi-tion shall not be made unless the conditions of the limiting Condition for Operation are met without reliance on provisions contained in the ACTION statements unless otherwise excepted. This provision shall not orevent passage throuah OPERATIONAL MODES as required to comply with ACTION statements.

3.0.5 When a system, subsystem, train, component or device is determined to be inoperable solely because its emeroency power source is inoperable, or solely because its normal power source is inoperable, it may be considered OPERABLE for the purpose of satisfying the requirements of its applicable Limiting Condition for Operation, provided:

(1) its corresponding normal or emercency power source is OPERABLE; and (2) all of its redundant system (s),

subsystem (s), train (s), component (s) and device (s) are OPERABLE, or likewise satisfy the requirements of this specification. Unless both conditions (1) and (2) are satisfied, the unit shall be placed in at least HOT STANDBY within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months , in at least HOT SHUTDOWN within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and in at least COLD SHUTDONN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months . This specification is not applicable in MODES 5 or 6.

NORTH ANNA - UNIT 1 3/4 0-1 Amendment No. 19

1

-.s APPLICABILITY a

SURVEILLANCE REQUIREMENTS (Continued) 4.0.1 Surveillance Requirements shall be applicable during the OPERATIONAL MODES or other conditions specified for individual Limiting Conditions for i

Operation unless othemise stated in an individual Surveillance Requirement.

]'

t 1

4.0.2 Each Surveillance Requirement shall be perfonned within the specified time interval with:

a.

A maximum allowable extension not to exceed 25% of the surveiM anc.e interval, and b.

A total maximum combined interval time for any 3 consecutive surveillance intervals not to exceed 3.25 times the specified surveillance interval.

4.0.3 Performance of a Surveillance Requirement within the specified time interval shall constitute compliance with OPERABILITY requirements for a Limitino Condition for Operation and Associated ACTION statements unless othemise required by the specification. Surveillance Requirements do not have to be performed on inoperable equipment.

a.0.4 Entry into an OPERATIONAL MODE o'r other specified applicability condition shall not be made unless the Surveillance Requirement (s) associated with the Limiting Condition for Operation have been performed within the stated t

surveillance interval or as othemise specified.

4.0.5 Surveillance Requirements for inservice inspection and testing of ASME Code Class 1, 2, and 3 components shall be applicable as follows:

a.

Inservice inspection of ASME Code Class 1, 2, and 3 components and inservice testing of ASME Code Class 1, 2, and 3 pumps and valves shall be performed in accordance with Section XI of the ASME Boiler and Pressure Vessel Code and applicable Addenda as required by 10 CFR 50 Section 50.55a(g), except where specific written relief has been granted by the Comission pursuant to 10 CFR 50, Section 50.55a(g)(6)(i).

NORTH ANNA - UNIT 1 3/a 0-2 Amendment No.19

l I

APPLICABILITY SURVEILLANCE REOUIREMENTS (Continued) b.

Surveillance intervals specified in Section XI of the ASME Boiler and Pressure Vessel Code and applicable Addenda for the inservice inspection and testing activities required by the ASME Boiler and Pressure Vessel Code and apolicable Addenda shall be applicable as follows in these Technical Soecifications:

ASME Boiler and Pressure Vessel Required frequencies for Code and applicable Addenda performino inservice terminology for inservice inspection and testino insoection and testina activities activities Weekly At least once per 7 days Monthly At least once per 31 days Guarterly or every 3 months At least once per 92 days Semiannually or every 6 months At least once per 184 days Every 9 months At least once oer 276 days Yearly or annually At least once per 366 days c.

The provisions of Specification 4.0.2 are aoplicable to the above required frequencies for performino inservice inspection and testing s

activities.

~

i d.

Performance of the above inservice inspection and testino activities shall be in addition to other soecified Surveillance Requirements.

i e

Nothing in the ASME Boiler and Pressure Vessel Code shall be construed to supersede the requirements of any Technical Soecification.

NORTH ANNA - UNIT 1 3/4 0-3 Amendment No. 19

e-E4

[

TABLE 3.3-3 (Continued) zs ENGINEERED SAFETY FEATORE INTERLOCKS g

ALLOWABLE y

DESIGNATION CONDITION SETPOINT VALUES FUNCTION P-ll With 2 of 3 pressurizer 2000 psig

-< 2010 psig P-ll prevents manual block of pressure channels above safety injection actuation on setpoint low-low pressurizer pressure.

With 2 of 3 pressurizer 1980 psig

-< 1990 psig P-il allows manual block of pressure channels below safety injection actuation on setpoint low-low pressurizer pressure.

P-12 With 2 of 3 T channels 543 F (Nominal)

< 545*F P-12 prevents manual block of 9

safety injection actuation on above setpoin high steam line flow.

g u

With 2 of 3 T channels 543 F (Nominal)

> 541*F P-12 allows manual block of w

safety injection actuation on bl below setpoint high steam line flow.

i Bn

~.-

i jg TABLE 3.3-4 ENGINttaED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION TRIP SETPOINTS h

I" FUNCTIONAL UNIT TRIP SETPOINT ALLOWABLE VALUES 1

1.

SAFETY INJECTION, TURBINE TRIP AND

-4 FEEDWATER ISOLATION a.

Manual Initiation Not Applicable Not Applicable b.

Automatic Actuation Logic Not Applicable Not Applicable c.

Containment Pressure--High

< 17 psia'

< 18.5 psia l

M*

d.

Pressurizer Pressure -- Low-Low 3,1765 psig 3.1755 psig

'C'

?!

e.

Differential Pressure

< 100 osi

< 112 psi Between Steam Lines--High f.

Steam Flow in Two Steam Lines--

< A function defined as

< A function defined as High Coincident with T

--Low-Low Tollows: a Ap correspond Tollows: a Ap corresponding a

or Steam Line Pressure y00w ing to 40% of full steam to 44% of full steam flow i

flow between 0% and 20%

between 0% and 20% load and j"

load and then a Ap increas-then a Ap increasing linear ing linearly to a Ap corre ly to a Ap corresponding to a

g sponding to 110% of full 111.5% of full steam flow steam flow at full load at full load sa

> 542 F Ef T

-> 543 F Tav -

1,

1. ggg psig steam line 3,505psigsteamline a

pressure pressure

.os G

q. -

i 5

Y:o TABLE 3.3-4 (Continued)

E ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION TRIP SETPOINTS e

E FUNCTIONAL UNIT TRIP SETPOINT ALLOWABLE VALUES G

2.

CONTAINMENT SPRAY a.

Manual Initiation Not Applicable Not Applicable l

i b.

Automatic Actuation Logic Not Applicable Not. Applicable 1 9.25 psia l

l c.

Containment Pressure--High-High 1 27.75 psia 2

l 3.

CONTAINMENT ISOLATION l

m

,f a.

Phase "A" Isolation m

b 1.

Manual Not Applicable Not Applicable l

2.

From Safety Injection Not Applicable Not Applicable Automatic Actuation logic b.

Phase "B" Isolation 1

1.

Manual Not Applicable Not Applicable

{

2.

Automatic Actuation Logic Not Applicable Not Applicable 3.

Containment Pressure--High-High 1 27.75 psia 129.25 psia l

J 5

E 4

4 e

i

h TABLE 3.3-4 (Continued)

^x ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION TRIP SETPOINTS

,3 i

E?

E FUNCTIONAL UNIT TRIP SETPOINT ALLOWABLE VALUES c-.

4.

STEAM LINE ISOLATION a.

Manual Not Applicable Hot Applicable b.

Automatic Actuation Logic Not Applicable Not Applicable c.

Containment Pressure--Intermediate 117,0 psia 1 19,3 psia l

liigh-liigh d.

Steam Flow in Two Steam lines--

< A function defined as

< A function defined as R

liigh Coincident with T

--Low-Low Tollows: a ap correspond-follows: a ap corresponding OrSteamLinePressureyEow ing to 40% of full steam to 44% of full steam flow a

flow between 0% and 20%

betwaen 0% and 20% load and

'f M

load and then a op increas-then a op increasing linearly ing linearly to a ap corre-to a op corresponding to sponding to 110% of full 111.5% of full steam flow steam flow at full load, at full load.

T,yg >_ 543 F avg '- 542'P T

> 600 psig steam line

> 585 psig steam line 9

pressure pressure 5.

TURBINE TRIP AND FEEDWATER ISOLATION n

a.

Steam Generator Water level--

1 75% of narrow range

< 76% of narrow range P

liigh-liigh instrument span each steam Instrument span each steam generator generator

2 TABLE 3.3-4 (Continued) x g;

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION TRIP SETPOINTS h

E FUNCTIONAL UNIT TRIP SETPOINT ALLOWABLE VALUES 6.

AUXILIARY FEEDWATER PUMP START a.

Steam Generator Water 2;18%of narrow range 2;17%of narrow range l

instrument span each instrument span each Level Low-Low.

steam generator steam generator 4

b.

S.I.

See 1 above (All S.I. Setpoints) c.

Station Blackout 2,57.5% Transfer Bus Voltage 2,52.5% Transfer Bus Voltage d.

Trip of Main Feed Pump N.A.

H.A.

. t>

7.

LOSS OF POWER a

i>

a.

4.16 kv Emergency Bus Undervoltage P999 1 60 volts with a 2912 1 60 volts with a D;

(Loss of Voltage) 2.2 + 0.03 second time delay 3 1 0.03 second time delay b.

4.16 kv Emergency Bus Undervoltage 3744.+,1.4 volts with a 3619 i 1.4 volts with a (Degraded Voltage) 6011 s2cond time delay 75 1 3 second time delay N

an 8n O

i

EMERGENCY CORE COOLING SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) 2.

Verifying that each of the following pumps start auto-matically upon receipt of a safety injection test signal:

a)

Centrifugal charging pump, and b)

Low head safety injection pump.

f.

By verifying that each of the following pumps develop the indicated discharge pressure (after subtracting suction pres-sure) on recirculation flow when tested pursuant to Specifica-tion 4.0.5.

1.

Centrifugal charging pump >_2410 psig.

2.

Low head safety injection pump > 156 psig g.

By verifying that the following manual valves requiring adjustment to prevent pump " runout" and subsequent component damage are locked and tagged in the proper position for injection:

1.

Within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months following completion of any repositioning or maintenance on the valve when the ECCS subsystems are I

required to be OPERABLE.

2, At least once per 18 months.

1.

1-SI-188 Loop A Cold Leg 2.

1-SI-191 Loop B Cold Leg 3.

1-S1-193 Loop C Cold Leg 4.

1-SI-203 Loop A Hot Leg 5.

1-SI-204 Loop B Hot Leg 6.

1-SI-205 Loop C Hot Leg h.

By performing a flow balance test, during shutdown, following completion of modifications to the ECCS subsystems that alter the subsystem flow characteristics and verifying that:

1.

For high head safety injection lines, with a single pump running:

a) The sum of the injection line flow rates, excluding the highest flow rate, is > 384 gpm, and b) The total pump flow rate is < 650 gpm.

NORTH ANNA-UNIT 1 3/4 5-5 Aaendment No. 6,19

,.-c..

.,. - +

r

i EMERGENCY CORE COOLING SYSTEMS i

i ECCS SUBSYSTEMS - T,yg < 350*F LIMITING CONDITION.FOR OPERATION 1

i 3.5.3 As a minimum, one ECCS subsystem comprised of the following shall be OPERABLE:

One OPERABLE centrifugal charging pump #,

a.

I b.

One OPERABLE low head safety injection pump #, and c.

An OPERABLE flow path capable of transferring fluid to the reactor coolant system when taking suction from the refueling water storage tank upon being manually realigned or from the containment sump when the suction is transferred during the recirculation phase of operation or from the discharge of the outside recirculation spray pump.

APPLICABILITY: MODE 4.

ACTION:

a.

With no ECCS subsystem OPERABLE because of the inoperability of either the centrifugal charging pump or the flow path from the refueling water storage tank, restore at least one ECCS

}

subsystem to OPERABLE status within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or be in COLD j

SHUTDOWN within the next 20 hours2.314815e-4 days 0.00556 hours 3.306878e-5 weeks 7.61e-6 months .

b.

With no ECCS subsystem OPERABLE because of the inoperability of the low head safety injection pump, restore at least one ECCS subsystem to OPERABLE status or maintain the Reactor heat removal metN0s.ess than 350*F by use of alternate Coolant System T l

c.

In the event the ECCS is actuated and injects water into the Reactor Coolant System, a Special Report shall be prepared and submitted to the Comission pursuant to Specification 6.9.2 within 90 days describing the circumstances of the actuation and the total accumulated acteation cycles to date.

A maximum of one centrifugal charging pump and one low head safety injection pump shall be OPERABLE whenever the temperature of one or more of the RCS cold legs is less than or equal to 320*F.

NORTH ANNA-UNIT 1 3/4 5-6 Anendment No. 3,16 i

PLANT SYSTEMS AUXILIARY FEE 0 WATER SYSTEM LIMITING CONDITION FOR OPERATION 3.7.1.2 At least three independent steam generator auxiliary feedwater pumps and associated flow paths shall be OPERABLE with:

a.

Two motor driven feedwater pumps.

b.

One feedwater pump capable of being powered from an OPERABLE steam supply system.

APPLICABILITY: MODES 1, 2 and 3.

ACTION:

With one auxiliary feedwater pump inoperable, restore at least three auxiliary feedwater pumps (two capable of being powered from separate emergency busses and one capable of being powered by an OPERABLE steam supply system) to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in H0T SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . Specification 3.0.4 is not applicable during heatup into Mode 3 for specification 3.7.1.2.b.

SURVEILLANCE REQUIREMENTS 4.7.1.2 In addition to.the requirements of Specification 4.0.5, each auxiliary feedwater pump shall be demonstrated OPERABLE:

a.

At least once per 31 days by:

1.

Verifying that the steam turbine driven pump develops a discharge pressure of 1380 psig at a flow of 1 35 gpm on recirculation flow.L Verifying)that each valve (manual, power operated orin the flow p 2.

automatic or otherwise secured in position, is in its correct position, and NORTH ANNA - UNIT 1 3/4 7-5 Amendment No.

19

i PLANT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) b.

At least once per 18 months during shutdown by:

1.

Verifying that each automatic valve in the flow path actuates to its correct position on a safety injection test signal.

2.

Verifying that each auxiliary feedwater pump starts auto-matically upon receipt of each of the following:

a.

Safety infection b.

Loss of offsite power c.

Low-low level in any one steam generator d.

Trip of all main feed pumps.

Prior to entry into Mode 3 following Mode 5 performance of c.

a flow test of each auxiliary feedwater pump to verify the normal flow path frcm the condensate storage tank through l

the pump to its associated steam generator is required.

l l

l P

Amendment No.19 NORTH ANNA - UNIT 1 3/4 7-6

TABLE 3.7-4 (Continued)

SAFETY RELATED HYDRAULIC SNUBBERS

g A

x SNUBBER SYSTEM SNUBBER INSTALLED ACCESSIBLE OR HIGH RADIATION

.tiALLY DIFFICULT E

No.

ON, LOCATION (ELEVATION-AREA)# INACCESSIBLE ZONE **

TO R,.CVE

^

7 (A or I)

(Yes or No)

E G

814 CH-251-C I

Yes No 802 CH-262-C I

Yes Yes 815 CH-235-C I

Yes Yes 859 CH-226-10 A

No No R

[

860 CH-222-11 A

No No a

'. 87 CH-244-12 I

Yes No 186 CH-244-12 I

Yes No 185 CH-251 -12 I

Yes Yes 842 CH-251-6 A

No No 189 CH-244-Pent A

No No 190 CH-244-Pent A

No Yes 191 CH-244-Pent A

,10 No

. ~. _

TABLE 3.7-4 (Continued)

' SAFETY RELATE 0 HYDRAULIC SNUBBERS

g l

M" i

y SNUBBER SYSTEM SNUBBER INSTALLED ACCESSIBLE OR HIGH RADIATION ESPECIALLY DIFFICULT TO REmVE g

No.

ON, LOCATION (ELEVATION-AREA)# INACCESSIBLE ZONE **

(Yes or No)

(A or I)

(Yes or L }

B E

188 CH-244-Pent A

No No

~

806 CH-251-A I

Yes No 203A OS-338-111[

I No Yes I

No Yes 2038 05-338-1113 A

No No 207 OS-267-1113 a2 209A OS-333-2 I

No Yes i.

y L

209B 0S-338-2 I

No Yes 800 OS-?74-OSil A

No No 801 0S-274-0511 A

No No 802 OS-272 OSH A

No No R

803 OS-270 OSH A

No No 2

R 804 OS-270-OSH A

No No 9

==-

._-.-s mu

TABLE 3.7-4 (Continued) gg SAFETY RELATED HYDRAULIC SNUBBERS

E 1

3:

SNUBBER SYSTEM SNUBBER INSTALLED ACCESSIBLE OR HIGH RADIATION ESPECIALLY DIFFICULT E

No.

ON, LOCATION (ELEVATION-AREA)# INACCESSIBLE ZONE **

TO REMOVE

(*

(A or 1)

(Yes or No)

(Yes or No) 5 U

100 RC-247-A I

Yes No 101 RC-246-A I

Yes No 102 RC-234-18 I

No Yes R>

N L,

1 04 RC-278-P I

Yes Yes 105 RC-278-P I

Yes Yes 1 06 RC-308-P I

Yes No 1 07 RC-308-P

i I

Yes No e

jy' 108 RC-232-9 3/4 I

No Yes i

3 109 RC-235-6 I

Yes Yes P

g 110 RC-234-6 I

Yes Yes 111 RC-247-C I

Yes No

}

T

' TABLE 3.7-4 (Continued) h SAFETY PELATED HYDRAULIC SNUBBERS

E!

SNUBBER SYSTEM SNUBBER INSTALLED ACCESSIBLE OR HIGH RADIATION ESPECIALLY DIFFICULT 2"

No.

ON, LOCATION (ELEVATION-AREA)# INACCESSIBLE ZONE **

TO REMOVE

- TA or I)

(Yes or No)

E A

a 112 RC-247-C I

Yes No 113 RC-259-P I

Yes Yes ll4A RC-260-B I

Yes Yes 114B RC-258-P I

Yes Yes g

a

?

IISA RC-308-P I

Yes Yes W

115B RC-308-P I

Yes Yes ll6A RC-308-P I

Yes Yes 1168 RC-308-P I

Yes Yes 117 RC-308-P I

Yes No 118 RC-308-P I

Yes No 119A RC-306-P I

Yes No l

1198 RC-306-P I

Yes No l

l "a.,

TABLE 3.7-4 (Continued)

SAFETY RELATED HYDRAULIC SNUBBERS

8 h

SNUBBER SYSTEM SNUBBER INSTALLED ACCESSIBLE OR HIGH RADIATION ESPECIALLY DIFFICULT e

2-No.

ON, LOCATION (ELEVATION-AREA)# INACCESSIBLE ZONE **

TO REMOVE i

j (A or I)

(Yes or No)

{

s t

"zM 120 RC-310-P I

Yes No

~

I 121 RC-302-P I

Yes Yes

{

i 122 RC-303-P I

Yes Yes I'

123 RC-303-P I

Yes Yes f

124A RC-306-P I

Yes No s

h 124B RC-306-P I

Yes No 125 RC-306-P I

Yes Yes 126 RC-307-P I

Yes No 127 RC-307-P I

Yes No 128 RC-302-P I

Yes Yes 129 RC-301-P I

Yes No 130 RC-302-P I

Yes No

Table 3.7-4 (Continued) ll SAFETY RELATED HYDRAULIC SNUBBERS

1 N

SNUBBER SYSTEM SNilBBER INSTALLED ACCESSIBLE OR HIGH RADIATION ESPECIALLY DIFFICULT 2=

No.

ON, LOCATION (ELEVATION-AREA)# INACCESSIBLE ZONE **

TO REMOVE (A or I)

(Yes or No)

(Yes or No) z G

~~

131 A RC-306-P I

Yes No i

131B RC-306-P I

Yes No 132 RC-307-P I

Yes No 133 RC-302-P I

Yes Yes w

d 134 RC-304-P I

Yes Yes M

135 RC-304-P I

Yes Yes 136A RC-306-P I

Yes Yes 1368 RC-306-P I

Yes No

p m

i 136C RC-306-P I

Yes Yes

]

137 RC-306-P I

Yes No i

?

450 CC-229-RCB I

Yes Yes e

853 RC-256-A I

Yes Yes i

856 RC-256-A I

Yes Yes

Table 3.7-4 (Continued)

SAFETY RELATED HYDRAULIC SNUBBERS

g 5

I SNUBBER SYSTEM SNUBBER INSTALLED ACCESSIBLE OR HIGH RADIATION ESPECIALLY DIFFICULT g

No.

ON, LOCATION (ELEVATION-AREA)# INACCESSIBLE ZONE **

TO REMOVE (A or I)

(Yes or No)

C z

-4 221B SHP-300-SB A

No No t

222A SHP-300-SB A

No Yes 222B SHP-300-SB A

No No 224 SHP-300-SB A

No No 225A SHP-300-SB A

No No s"

[

225B SHP-300-SB A

No No a

226 SHP-300-SB A

No No 227A SHP-300-SB A

No No 227B SHP-300-SB A

No Yes 228A SHP-300-SB A

No No 229 SHP-300-SB A

No No

Table 3.7-4 (Continued)

SAFETY RELATED HYDRAULIC SNURBERS*

S w*

S$ LUBBER SYSTEM SNUBBER INSTALLED ACCESSIBLE OR HIGH QA0!ATION ESPECIALLY DIFFICULT 5E No.

ON, LOCATION (ELEVATION-AREAL # INACCESSIBLE ZONE **

TO REH0VE I

(A or I)

(Yes or No)

'g E

i

[

400A SI-258-13 I

No Yes i

4008 SI-258-13 I

No Yes 400C SI-258-13 I

No Yes-400D SI-258-13 I

No Yes 100A 51-256-SG A

No No w

D 1008 SI-256-SG A

No No

?

E 101A SI-256-SG A

No No 101B SI-256-SG A

No No 102A SI-256-SG A

No No 102B SI-256-SG A

No No k

104A SI-256-SG A

No No 5

G W

-- s

....mm

-.,--m_u

~

t.

Table 3.7-4 (Continued)

SAFETY RELATED HYDRAULIC SNUBBERS

S 58 SNUBBER SYSTEM SNUBBER INSTALLED ACCESSIBLE OR HIGH RADIATION ESPECIALLY DIFFICULT No.

ON, LOCATION (ELEVATION-AREA)# INACCESSIBLE ZONE **

TO REMOVE (A or I)

(Yes or No)

E_,

2 234 FH-300-SB A

No No 245A FH-295-FHH A

No Yes J

245B Fif-295-FWH A

No Yes 246 FW-295-rih A

No Yes 1

233 SDHV.307-MSVH A

No No 4

%(

233A SDHV-307-MSVH A

No No i

234 SDHV-307-MSVH A

No No 235 SDHV-307-MSVH A

No Yes 236 SDVH-297-MSVH A

No No k

J i

n

,x e

Table 3.7-4 (Continued)

SAFETY RELATED HYDRAULIC SNUBBERS

8 x5 SNUBBER SYSTEM SNUBBER INSTALLED ACCESSIBLE OR HIGH RADIATION ESPECIALLY DIFFICULT 3

No.

ON, LOCATION (ELEVATION-AREA)# INACCESSIBLE ZONE **

TO REMOVE y

(A or I)

(Yes or No)

(Yes or No) 0 E]

200 WS-256-SG A

No No 201 WS-256-SG A

No No 202 WS-244-ABB-A No No 203 WS-244-ABB A

No No 204A WS-244-ABB A

No No

?$

204B WS-244-ABB A

No Yes 206 WS-244-ABB A

No No 207 WS-244-ABB A

No No 208 WS-244-ABB A

No No 205A WS-244-ABB A

No No 205B WS-244-ABB A

No Yes O

m

i

.l Table 3.7-4 (Continued)

SAFETY RELATE 0 HYORAllLIC SNilBBERS*

2 S

5!

2 SNUBBER SYSTEM SNUBBER INSTALLED ACCESSIRLE OR HIGH RADIATION ESPECIALLY DIFFICULT No.

ON, LOCATION (ELEVATION-AREA)# _INACCESSIRLE ZONE **

TO REMOVE 2"

( A or I)

(Yes or No)

(Yes or No) i G

403 CC-?44-Pent A

No Yes 4 04 CC-244-Pent A

No Yes 405 CC-244-Pent A

No Yes 407 CC-244-Pent A

No No 409 CC-244-Pent A

No Yes

]

410 CC-244-Pent A

No Yes S

571 CC-252-AR A

No Yes 202 FC-249-FBB I

No No 204 FC-2a9-FBB I

No No k

a.

2:

?

Table 3.7-4 (Continued)

SAFETY RELATED HYDRAULIC SNUBBERS

54 SNUBBER SYSTEM SNUBBER INSTALLED ACCESSIBLE OR HIGH RADIATION ESPECIALLY DIFFICULT No.

ON, LOCATION (ELEVATION-AREA)# INACCESSIBLE ZONE **

TO REMOVE E

~

(A or I)

(Yes or No)

(Yes or No) 9 e

1 WGCB-246-A I

Yes Yes 2

WGCB-246-C I

Yes Yes 1A WGCB-244-Pent I

Yes No 2A WGCB-244-Pent I

Yes No 103 WGCB-279-TBM I

No Yes w

104 WGCB-279-TBM I

No Yes 2

?

E I

i

[

~

Table 3.7-4 (Continued) 5 SAFETY RELATED HYDRAULIC SNUBBERS

A 2

SNUBBER SYSTEM SNJBBER INSTALLED ACCESSIBLE OR HIGH RADIATION ESPECIALLY DIFFICULT s

No.

i 3

ON, LOCATION (EL EVATION-AREA)# INACCESSIBLE ZONE **

TO REMOVE (A or I)

(Yes or No)

B E

237 SAE-307-MSVH A

No No 238 SAE-307-MSVH A

No No 239 SAE-307-MSVH A

No No 240 SAE-307-MSVH A

No No 241 SAE-307-MSVH A

No No 242 SAE-307-MSVH A

?

No No S

243 SAE-297-MSVH A

No No 244 SAE-297-MSVH A

No No 245 SAE-297-MSVH A

No No

Table 3.7-4 (Continued) i SAFETY RELATED HYDRAULIC SNURBERS*

I n$

i 3

SNUBBER SYSTEM SNUBBER INSTALLED ACCESSIBLE OR HIGH RADIATION ESPECIALLY DIFFICULT

[

4 s

No.

nN, LOCATION (ELEVATION-AREA)# INACCESSIBLE ZONE **

TO REMOVE (A or I)

(Yes or No)

E U

246 SAE-279-AFH A

No No a

247 SAE-297-AFH A

No No 248 SAE-297-AFW A

No No 249 SAE-297-AFH A

No No 250 SAE-297-AFW A

No No 251 SAE-297-AFH A

No No h

252 SAE-297-AFH A

No No 253 SAE-297-AFH A

No No 254 SAE-297-AFN A

No No 255 SAE-297-AFH A

No No k

256 SAE-297-AFH A

No No R

3 257 SAE-297-AFH A

No No

?

G 9

^-

M

,i.

Table 3.7 A (Continued) ll 5

SAFEIv-RELATED HYDRAULIC SNUBBERS

a Ei!

3E SNUBBER SYSTEM SNU8BER INSTALLE0 ACCFSSIBLE OR HIGH RADIATION ESPECIALLY DIFFICULT No.

ON, LOCATION (ELEVATION-AREA)4 INACCESSIBLE 7ANE**

TO REMOVE (A or I)

(Yes or No)

{.

e g

I' G

280 SAE-305-MSVH A

No Yes 281 SAE-305-MSVH A

No Yes 282 SAE-305-MSVH A

No Yes l'

6:

m.

i-,

y m

7 l:

i h*

a i

a Ii

? :

D w

9

l I

TABLE'3.7-4 (Continued)

TABLE NOTATIONS

LOCATION ABBREVIATIONS j'

Abbreviations Area A

Cubicle A i

B Cubicle B f

C Cubicle C Pent.

Penetration Area Aux. Bldg.

7 P

Pressurizer Cubicle RCA Reactor Containment Annulus MSVH Main Steam Valve House MSH Main Steam Header - Turb. Bldg.

TBM Turbine Bldg. Mezzanine TBB Turbine Bldg. Basement i,

SB Service Bldg.

c4 Safeguards Bldg.

?

FWH Feedwater Header - Turb. Bldg.

ABB Auxiliary Bldg. Basement FBB Fuel Bldg. Basement AFW Auxiliary Feedwater Pump House NOTE: Numbers indicate radial locations in reactor containment.

Snubbers may be added to safety related systems without prior License Amendment to Table 3.7-4 provided that a revision to Table 3.7-4 is included with the next License Amendment request.

- Madifications to this table due to changes in high radiation areas shall be submitted to the NRC as part of the next License Amendment request.

NORTH ANNA - UNIT 1 3/4 7-66

P 3/4.0 APPLICABILIT_Y, BASES The specifications of this section provide the general requirements applicable to each of the Limiting Conditions for Operation and Surveil-lance Requirements within Section 3/4.

3.0.1 This specification defines the applicability of each spec-ification in tems of defined OPERATIONAL MODES or other specified conditions and is provided to delineate specifically when each spec-ification is applicable.

3.0.2 This specification defines those conditions necessary to.

constitute compliance with the tems of an individual Limiting Condition for Operation and associated ACTION requirement.

3.0.3 This specification delineates the ACTION to be taken for circumstances not directly provided for in the ACTION statements and whose occurrence would violate the intent of the specification. For example, Specification 3.5.1 calls for each Reactor Coolant System accumulator to be OPERABLE and provides explicit ACTION requirements when one accumulator is inoperable. Under the terms of Specification 3.0.3, if more than one accumulator is inoptable, the unit is required to be in at least HOT STANDBY within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 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 . As a further example, Specification 3.6.2.1 requires two Containment Quench Spray Systems to be OPERABLE and provides explicit ACTION requirements if one spray system is inoperable. Under the tems of Specification 3.0.3, if both of the required Containment Quench Spray Systems are inoperable, the unit is required to be in at least H0T STANDBY within I hour, in at least HOT SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and in at least COLD SHUTDOWN in the next 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

It is assumed that the unit is brought to the required l

MODE within the required times by promptly initiating and carrying out t

the appropriate ACTION statement.

3.0.4 This specification provides that entry into an OPERATIONAL MODE cr other specified applicability condition must be made wita (a) the full complement of required systems, equipment or components OPERABLE and (b) all other parameters as specified in the Limiting Conditions for Operation being met without regard for allowable deviations and out of service provisions contained in the ACTION statements.

i t

The intent of this provision is to insure that facility operation is not initiated with either required equipment or systems inoperable or other specified limits being exceeded.

i Exceptions to this provision have been provided for a limited umber of specifications when startup with inoperable equipment would n

l not affect plant safety. These exceptions are stated in the ACTION l

statements of the appropriate specifications.

NORTH-ANNA - UNIT 1 B 3/4 0-1 Amendment No. 19 l

7

.+=w--

C-

"t T

ADPLICABILITY BASES 3.0.5 This soecification delineates what additional conditions must be satisfied to pemit operation to continue, consistent with the ACTION statements for power sources, when a normal or emeroency power source is not ODEMBLE.

It specifically prohibits coeration when one division is inoperable because its normal or emergency power source is inocerable and a system, subsystem, train, comconent or device in another division is inoperable for another reason.

The orovisions of this soecification permit the ACTION statements associated with individual systems, subsystems, trains, components, or devices to be consistent with the ACTION statements of the associated electrical power source.

It allows coeration to be coverned by the time limits of the ACTION statement associated with the Limiting Condition for Operation for the normal or emergency power source, not the individual ACTION statements for each system, subsystem, train, comoonent or device that is determined to be inoperable solely because of the inocerability of its normal or emeroency oower source.

For example, Specification 3.8.1.1 recuires in part that two energency diesel generators be OPERABLE. The ACTION statement orovides for a 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months out-of-service time when one emeraency diesel cenerator is not ODEDABLE.

If the definition of ODERABLE were applied without consideration of Soecification 3.0.5, all systems, subsystems, trains, components and devices sucolied by the inoperable emergency oower source would also be inoperable. This would dictate invokina the applicable ACTION statements for each of the aoplicable Limiting Conditions for Operation. However, the orovisions of Soecification 3.0.5 permit the time limits for continued operation to be consistent with the ACTION statement for the inoperable emercency diesel aenerator instead, pro-vided the other specified conditions are satisfied.

In this case, this would mean that the correspondino normal oower source must be OPERABLE, and all redundant systems, subsystens, trains, components, and devices must be OPERABLE, or otherwise satisfy Soecification 3.0.5 (i.e., be capable of performina their desian function and have at least one normal or one emercency power source OPERABLE).

If they are not satisfied, shutdown is required in accordance with this specification.

As a further example, Specification 3.8.1.1 requires in cart that two physically independent circuits between the offsite transmisson network and the onsite Class IE distribution system be OPERABLE. The ACTION statement provides a 2a-hour out-of-service time when both required offsite circuits are not ODERABLE.

If the definition of ODERABLE were applied without consideration of Soecification 3.0.5, all systems, subsystems, trains, comoonents and devices supplied by the inoperable normal power sources, both of the offsite circuits, would also be inoperable. This would dictate invokina the applicable NORTH ANNA - UNIT 1 9 3/a 0-2 Amendment No.19

APPLICABILITY BASES ACTION statements for each of the applicable LCOs.

However, the pro-visions of Specification 3.0.5 pennit the time Ifmits for continued operation to be consistent with the ACTION statement for the inoperable normal power sources instead, provided the other specified conditions are satisfied.

In this case, this would mean that for one division the emergency power source must be OPERA 9LE as must be the components supplied by the emergency power source) a(nd all redundant systems, subsystems, trains, components and devices in the other division must be OPERABLE, or likewise satisfy Specification 3.0.5 (f.e., be capable of performing their design functions and have an emeraency power source OPERABLE).

In other words, both emergency power sources must be OPERABLE and all redundant systems, subsystems, trains, components and devices in both dividfons must also be OPERABLE.

If these conditions are not satisfied, shutdown is required in accordance with this specification.

t In MODES 5 or 6, Specification 3.0.5 is not applicable, and thus the individual ACTION statements for each applicable Limiting Condition for Operation in these MODES must be adhered to.

d.0.1 This specification provides that surveillance activities necessary to insure the Limiting Conditions for Operation are met and will be perfonned during the OPERATIONAL *ionES or other conditions for which the Limiting Conditions for Operstion are applicable.

Provisions for additional surveillance activities to be performed without regard to the applicable OPERATIONAL MODES or other conditions are provided in the individual Surveillance Requirements. Surveillance Requirements for Special Test Exceptions need only be perfonned when the Special Test Exception is being utilized as an exception to an individual specification.

4.0.2 The provisions of this specification provide allowable tolerances for performing surveillance activities beyond those spect-fied in the nominal surveillance interval.

These tolerances are necessary to provide operational flexibility because of scheduling and performance considerations. The phrase "at least" associated with a surveillance frequency does not negate this allowable tolerance value and permits the performance of more frequent surveillance activities.

l The tolerance values, taken either individually or consecutively over 3 tests intervals, are sufficiently restrictive to ensure that the reliability associated with the surveillance activity is not significantly l

degraded beyond that obtained from the nominal specified interval.

t l

4.0.3 The provisions of this specification set forth the criteria for determination of compliance with the OPERARILITY requirements of the Limiting Conditions for Operation. !!nder this criteria, equipment, systems or components.are assumed to be OPERABLE if the associated NORTH ANNA - UNIT 1 8 3/4 0 3 Amendment No.19 i

i APPLICABILITY BASES i

l surveillance activities have been satisfactorily performed within the l

specified time interval. flothing in this provision is to be constured j

l as defining equipment, systems or components OPERABLE, when such items 1

are found or known to be inoperable although still meeting the Surveil-i lance Requirements.

l 4.0.4 This specification ensures that the surveillance activities associated with a Limiting Condition for Operation have been performed within the specified time interval prior to entry into an OPERATIOilAL fiODE or other applicable condition. The intent of this provision is to ensure that surveillance activities have been satisfactorily demonstrated on a current basis as required to meet the OPERABILITY requirements of the Limiting Condition for Operation.

Under the terms of this specification, for example, during initial i

plant startup or following extended plant outages, the applicable surveillance activities must be performed within the stated surveillance interval prior to placing or returning the system or equipment into OPERABLE status.

4.0.5 This specification ensures that inservice inspection of ASME Code Class 1, 2 and 3 components and inservice testing of AS!1E Code Class 1, 2 and 3 pumps and valves will be cerformed in accordance with a periodically updated version of Section XI of the ASME Boiler i

and Pressure Vessel Code and Addenda as required by the 10 CFR 50.55a.

Relief from any of the above requirements has been provided in wirting by the Comission and is not a part of these Technical Specifications.

This specification includes a clarification of the frequencies for i

performing the inservice inspection and testing activities required by l

Section XI of the ASME Boiler and Pressure Vessel Code and applicable Addenda. This clarification is provided to ensure consistency in surveillance intervals throughout these Technical Specifications and i

to remove any ambiguities relative to the frequencies for performing i

the required inservice inspection and testing activi*.ies.

Under the terms of this specification, the more restrictive requirements of the Technical Specifications take precedence over the l

ASME Boiler and Pressure Vessel Code and applicable Addenda.

For example, the requirements of Specification 4.0.4 to perform surveillance acti-i vities prior to entry into an OPERATIONAL %DE or other specified applicability condition takes precedence over the ASME Boiler and Pressure Vessel Code provision which allows pumps to be tested up to l

one week after return to normal operation. And for example, the Tech-j nical Specification definition of OPERABLE does not grant a grace period before a device that is not capable of perfonning its specified function is declared inoperable and takes precedence over the ASME Boiler and Pressure Vessel Code provision which allows a valve to be l

incapable of performing'its specified function for up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months before being declared inoperable.

NORTH ANNA - UNIT 1 B 3/4 0-4 Amendment No.19 l

S.0 ADMINISTRATIVE CnumCS 6.1 RESDONSIRILITV 6.1.1 The Station Maqacer shall be rasnonsible for overall facilitv nneration and shall deleoate in writinn the succession to this resnonsibility durino his absence.

6.1.2 The Shift Supervisor (or during his absence from the Control Room, a designated individual) shall be responsible for the Control Room comand function and shall be the only individual that may direct the licensed activities of licensed operators. A managenent directive to this effect, signed by the Executive Vice President, Power, shall be reissued to all station personnel on an annual basis.

6.2 ORGANIZATION OFFSITE 6.2.1 The offsite organizatien for facility management and technical support shall be as shown on Figure 6.2-1.

FACILITY STAFF 6.2.2 The Facility organization shall be as shown on Figure 6.2-2 and:

a.

Each on duty shift shall be composed of at least the minimum shift crew composition shown in Table 6.2-1.

b.

At least one licensed Reactor Operator shall be in the control room when fuel is in the reactor.

In addition, while the unit is in MODES 1, 2, 3 or 4, at least one licensed Senior Reactor Operator shall be in the Control Room.

c.

A health physics technician # shall be on site when fuel is in the reactor.

d.

ALL CORE ALTERATIONS shall be observed and directly supervised by either a licensed Senior Reactor Operator or Senior Reactor l

Operator Limited to Fuel Handling who has no other concurrent responsibilities during this operation.

i l

A Fire Brigage of at least 5 members shall be maintained onsite e.

at all times.

l The Fire Brigade shall not include the minimum shift crew shown in Table 6.2-1 or any personnel required for i

other essential functions during a fire emergency.

The health ohysics techniciaq and Fire Rricade connosition may be less than the minimum reouf rements for a Deriod of time not to exceed 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months in order to accommodate unexnected absence nrovided immediate action is taken to fill the reouired nositions.

NnRTH ANNA - flNIT 1 6-1 amendment No. /, Jg,19

v 2

O D

'Ja EXECUTIVE Z

VICE PRESIDEh!

2 POWER

p C2 e-g

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EXECUTIVE MAN AGER MANAGER MANAGER tiCEh$thG AhD huCLEAR NUCLEAR QU All1Y ASSURANCE OPE RA180b$ & M AINT.

IECHhtCAL SERVICE 5

$71 TEM hu(LE AR SAFETV A40 OPE R ATING COMMiliEl 04 REC 10R huCLEAR DIRECTOR DIRE CTOR DaRECTOR m

CHEMISTRY AND B

SI All0N OPE R ATION AND SAffiVEVALUAlluN ggggggggg gggggggg N

MANAGERS mal 41t h AhCE SE RVICES AND CONT ROL HE ALIN PHY14C3 STAI40msurERV610R SAIETY EhGlhE E RikG SECIl0hsuPV SE Cllom suvP M IiON SUPV OPERATION AhD AOMikiSIH A TIVE I Athl4G MA14TENAhCE SUPruRT SE RVICE S 3=

H

RESPONSIBL E f 0H CORPORATE IIRE PROTE CTION PROGRAM n.

9 tu 3

Fegure 6.21 Of fuse Organisatani t.w Facihty Maugement avl Inhnscal FupsunE zO

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l NORTH ANNA - UNIT 1 6-1 Amendment No. 3, JJ,17 t

~

.. =

TABLE 6.2-1 MINIMUM SHIFT CRE.s COMPOSITIOM WITH UNIT 2 IN MODE 5 OR 6 OR DE-FUELED POSITION NUMBER OF INDIVIDUALS REQUIRED TO FILL POSITION MODES 1, 2, 3, & 4 MODES 5 & 6 a '* '

a 1

1 55 r

SRO 1

none RO 2

1 D

A0 2

2 STA 1

none

{

WITH UNIT 2 IN MODES 1, 2, 3, OR 4 POSITION NUMBER OF INDIVIOUALS REQUIRED TO FILL POSITION MODES 1, 2, 3, & 4 MODES 5 & 6 8

SS l'

1 8

SRO 1

none b

RO 2

y A0 2

1 8

STA 1

none

/ Individual may fill the same position on Unit 2.

N One of the two required individuals may fill the same position on Unit 2.

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NORTH ANNA

NIT l 6-4 Amendment No.19

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TABLE 6.2-1 (Contir.ued)

SS - Shift Supervisor with a Senior Reactor f>perators License on ' Unit 1.

SRO - Individual with a Senior Reactor Operators License on Unit 1 RO - Individual with a Reactor Operators License on Unit 1.

AO - Auxiliary Operator STA - Shift Technical Advisor "Except for the Shift Supervisor, the Shift Crew Composition may bd one less than the minimum requirements of Table 6.2-1 for a period of time not to exceed 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months in order to accommodate unexpected absence of on-duty shift crew members provided immediate action is taken to restore the Shift Crew Composition te within the minimum requiremenes of Table 6.7.-l.

This provision does not permit any shift crew position to be unmaaned upon shift change due to an oncoming shift crewman being late or absent.

During any absence of the Shift Supervisor from the Control Rocm while the unit is in MODE 1, 2, 3 or 4, an individual (other than the Shift Technical Advisor) with a valid SR0 license shall be designated to assume the Control Room command function.

During any absence of the Shift Supervisor from the Control Room while the unit is in MODE 5 or 6, on individual with a valid R0 license (other than the Shift Technical Advisor) shall be designated to assume the Control Room command function.

Licensed operators shall:

1.

Not work more than 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months straight; 2.

Not work more than 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months in any 48-hour period; f

3.

Not work more than 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months in any 7-day period; 4.

Not work more than 14 consecutive days without having 2 consecutive days off.

Deviation from these requirements may be authorized by the Station Manager in accordance with established procedures and with documentation of the cause.

Overtime limits do not include shift turnover time.

NORTH ANNA - UNIT 1 6-4a Amendment No. 19

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ML19331C286

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