Text

Responds to NRC 851010 Transmittal of Proof & Review Tech Specs Re Reactor Trip Sys Instrumentation & Esfas. Corrections to Errors Originating in SER Review Attached
	ML20133Q002
Person / Time
Site:	Catawba
Issue date:	10/30/1985
From:	Tucker H; DUKE POWER CO.
To:	Adensam E, Harold Denton; Office of Nuclear Reactor Regulation
References
	NUDOCS 8511010300
	Download: ML20133Q002 (22)
	v • d • e

s ..sg DuxE Powen GOMPANY P.O. moX 33189 CH A RI M RTE,N.C. 989 49 NALH. TUCKER vas.mposessa wwe -, (yo4) an>4aos October 30, 1985 Mr. Harold R. Denton, Director Office o Nuclear Reactor Regulation U. S. Nuclear Regulatory Commission Wtshington, D. C. 20555 Attention: Ms. E. G. Adensam, Chief Licensing Branch No. 4 Ret Catawba Nuclear Station, Units 1 and 2 Docket Nos. 50-413 and 50-414 Proof and Review Technical Specifications

Dear Mr. Denton:

'This letter is in response to your October 10, 1985 letter which transmitted the Proof and Review Technical Specifications for Catawba Units 1 and 2. l Attached are corrections to errors found by our review. At this time we have not identified any other statements which do not reflect the FSAR or the "as-built" facility. A review of the SER was conducted by Mr. Kimura of EG&G who is under contract by the NRC to conduct the review of the pro-posed Technical Specifications. During a meeting held in mid-July between Mr.'Kimura, members of your staff and Duke Power personnel, Mr. Kimura's review of the SER vis-a-vis the proposed Technical Specifications was discussed. It is our opinion that all of the concerns in regard to the SER and the Technical Specifications were resolved.

If you have any questions regarding this response please contact Mr. Roger W. Quellette at (704)373-7510.

Very truly yours, m

Hal B. Tucker RW0: sib Attachment i

f 8511010300 851030 '

PDR ADOCM 0$000413 P PM , ;

I I i

r Mr. Harold R. Denton, Director October 30, 1985 Page Two cc: Dr. J. Nelson Grace, Regional Administrator U. S. Nuclear Regulatory Commission Region II 101 Marietta Street, NW, Suite 2900 Atlanta, Georgia 30323 NRC Resident Inspector Catawba Nuclear Station Robert Guild, Esq.

P. O. Box 12097 Charleston, South Carolina 29412 Palmetto Alliance 2135 Devine Street Columbia, South Carolina 29205 Mr. Jesse L. Riley Carolina Environmental Study Group 854 Henley Place Charlotte, North Carolina 28207

TABLE 3.3-1 (Continued)

E g REACTOR TRIP SYSTEM INSTRUMENTATION 5

MINIMUM TOTAL NO. CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION

E -

[ 10. Pressurizer Pressure-High 4 2 3 1, 2 6# .

g 11. Pressurizer Water Level-High 3 2 2 1 7#

12. Reactor Coolant Flow-Low

a. Single Loop (Above P-8) 3/ loop 2/ loop in 2/ loop in 1 7#

any oper- each oper-ating loop ating loop

b. Two Loops (Above P-7 and 3/ loop 2/ loop in 2/ loop 1 7#

below P-8) two oper- each oper- ;

R a ating loops ating loop Y

13. Steam Generator Water 4/sta 2/sta gen 3/sta gen 1, 2 6# m Level--Low-Low gen in any each o operating operating M sta gen -

sta gen 9'

.o

14. Undervoltage-Reactor Coolant 4-1/ bus 2

Pumps (Above P-7) 3 1 6# s g

15. Underfrequency-Reactor Coolant 4-1/ bus 2 3 1 6# 0 Pumps (Above P-7) 0 o

16. Turbine Trip /p

a. Low Control Valve EH Pressure W h ) 2 3 1#### 7#

b. urbine Stop Valve Closure 4' 4 1 18### 11#

17. Safety Infection Input D

@" t::, from ESF ~ ~ - ~ -

2 1 2 1, 2 9 E I f D

= x bp M/C. .

hnll,shre (doel 7_

y

)

TABLE 3.3-2 (Continued) 9 y REACTOR TRIP SYSTEM INSTRUMENTATION RESPONSE TIMES

E 2

FUNCTIONAL UNIT RESPONSE TIME

E '

i Q

vs

12. Low Reactor Coolant Flow

a. Single Loop (Above P-8) < 1 second g b. Two Loops (Above P-7 and below P-8) ?Isecond '

N

13. Steam Generator Water Level-Low-Low _< 2.0 seconds

14. Undervoltage-Reactor Coolant Pumps _< 1.5 seconds

15. Underfrequency-Reactor Coolant Pumps < 0.6 second h

a w

16. Turbine Trip r "

A eo Y

a.

b.

Low Control Valve EH Turbine Stop Valve Closure ' Pressu (re Ginif O ' N.A. 2 -

t as N.A. $ .

17. Safety Injection Input from ESF N.A.

18. Reactor Trip System Interlocks o N.A. y j 19. Reactor Trip Breakers N.A.

20. Automatic Trip and Interlock Logic N.A. g ,

.~. -

l g i - .

llmm

( Lou $4ep Whe (N bc5MC & k '

lj ON ~

i -

) A GD 5%

l l-9 TABLE 4.3-1 (Continued) f '.

9 REACTOR TRIP SYSTEM INSTRUMENTATION SURVEILLANCE REQUIREMENTS

5 2

l

' TRIP .

ANALOG ACTUATING E CHANNEL DEVICE MODES FOR Q WICH CHANNEL CHANNEL OPERATIONAL OPERATIONAL ACTUATION FUNCTIONAL UNIT SURVEILLANCE CHECK CALIBRATION TEST TEST LOGIC TEST IS REQUIRED R 13. Steam Generator Water Level- S R M N.A. N.A. 1, 2

, Low-Low

14. Undervoltage - Reactor Coolant N.A. R N.A. M N. A. 1 >

Pumps .

15. Underfrequency - Reactor N.A. R N.A. M N.A. 1 Coolant Pumps .

R

16. Turbine Trip m 3

a. Low control Valve EH C

[

i T _ Pressure g W N.A. R N.A. S/U(1,10) N.A. 1# %

b. Turbine Stop Valve N.A. R N.A. S/U(1,10) N.A. 1#

Closure

17. Safety Injection Input from N.A. N.A. N.A.

ESF R N.A. 1, 2 Q

18. Reactor Trip System Interlocks o"

a. Intermediate Range Q

Neutron Flux, P-6 N.A. R(4) M N.A. N.A. 2##

b. Low Power Reactor Trips 8 lock, P-7 N.A. R(4) M(8) N.A. N.4 c 1 .

c. Power Range Neutron a Flux, P-8 N.A. R(4) N.A.

M(8) N.A. 1 Q d. Low Power Range Neutron Flux 7 P-9 ~ ~ N.A. R(4) N(8) N.A. N.A. I n / w ,

5 Y6 m ( f C O 5 0 ff. ( M ai k '

/ -

),

TA8LE 3.3-3

{ ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION 5

e MINIMUM 5 TOTAL NO. CHANNELS CHANNELS FUNCTIONAL UNIT APPLICA8LE I C, OF CHANNELS TO TRIP OPERABLE MODES ACTION l' 1. Safety Injection (Reactor

> -Trip, Phase "A" Isolation, l

5 Feedwater Isolation Control u Room Area Ventilation Opera-tion, Auxiliary Feedwater f Motor-Drivan Pump, Purge 4 .

Exhaust Isolation,JnnulusjenI.I on Operation,-Auxiliary'BuQding Filtered 'f...". M C. Exhauit i

Operation,-Emergency-Didsel Generator Operation, Component I

4

Cooling Water, Turbine Trip, ,

and Nuclear Service Water y Operation) 4 ui ,

a. Manual Initiation 2 1 2 l', 2, 3, 4 18 -

i' b. Automatic Actuation Logic and Actuation 2 -1 2 1,2,3,4 14 3

o.

Relays - %

Re

c. Containment 3 2 o 2 1,2,3 15*

Pressure-High . .- Q i

~

d. Pressurizer 4 2 3 1, 2, 3# 19*

h n.

Pressure-Low .

t

e.

Q Steam Line Pressure- 3/ steam ifne 2/ steam line 2/ steam line Low 1, 2, 3# 15*

- in any steam G5 line 4F8

TABLE 3.3-10 (Continuedl h

> ACCIDENT MONITORING INSTRUMENTATION h TOTAL MINIMUM INSTRUMENT NO. OF CHANNELS e

CHANNELS 5 OPERABLE d 15. In Core Thermocouples 4/ core quadrant 2/ core quadrant z 16. Unit Vent - High-High Range Area Monitor (EMF-54) N.A. 1 b 17. Steam b ief Valve Exhaust Radiation Monitor (~1 EMF-26, 27, 28 or 29 and 2'\E$10h11'.12 or 13) N.A. I

18. Contain\

een ' Arda-HighRangeRadiationMonitor(EMF-53Aor8)

N.A. I 19.

N )

Reactor VesseLWater Level 2 1

20. Reactor Coolant Radiation Level (EMF-48) N.A. 1 Y.

Y O .

TABLE NOTATIONS

Not applicable if the associated block valve is in the closed position.

o

- Not applicable if the associated block valve is in t.he closed position and power is removed. o r

Go

~

-O g

H e

~

4 N -

w YN

PR00f M opy C

TABLE 3.4-1 (Continued)

. REACTOR COOLANT SYSTEM PRESSURE ISOLATION VALVES VALVE NUMBER FUNCTION '

ND18*

', ND2A* /

/ .AKfC *Residaal lba "'**Y

.AHf()Q,;g g //ul '?% / wa./

NO368*# M 7 D e' 4 N /d - "' a N

+ND37A*#

\ WTe& dad fedheye/

N s.* Testing per Specification 4.4.6.2.2d. not applicable due to positive indication of valve position in Control Room.

1.

. Leakage rates less than or equal to 1.0 gpm are considered acceptable.

2.

Leakage rates greater than 1.0 gpm but less than or equal to 5.0 gpm are considered acceptable if the latest measured rate has not exceeded the rate determined by the previous test by an amount that reduces the margin between measured leakage rate and the maximum permissible rate of 5.0 gpm by 50% or greater.

3.

Leakage rates greater than 1.0 gpm but less than or equal to 5.0 gpm are considered unacceptable if the latest measured rate exceeded the rate determined by the previous test by an amount that reduces the margin between measured leakage rate and the maximum permissible rate of 5.0 gpm by 50% or greater.

4.

Leakage rates greater than 5.0 gpm are considered unacceptable.

OCT 1 80 -

CATAWBA - UNITS 1 AND 2 3/4 4-23

Akh(

EMERGENCY CORE COOLING SYSTEMS b/QybOPP SURVEILLANCE REQUIREMENTS (Continued)

b. At least once per 31 days and within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months after each solution volume increase of greater than or equal to 75 gallons by verifying the boron concentration of the accumulator solution;

c. At least once per 31 days when the Reactor Coolant System pressure is above 1000 psig by verifying that power is removed from the isolation valve operators on Valves NI54A, NI658, 176A, and NI888 and that the respective circuit breakers are padio 4.5.1.1.2 Each cold leg infection accumulator water level and pressure channel shall be demonstrated OPERABLE:

a. At least once per 31 days by the performance of an ANALOG CHANNEL OPERATIONAL TEST, and -

t

b. At least once per 18 months by the performance of a CHANNEL CALIBRATION.

CATAWBA - UNITS 1 AND 2 3/4 5-2

. ~ . - - - - - - - . . . . - . . - - . - . -

PROOF & R&Igy copy -

3/4.7.5 STANDBY NUCLEAR SERVICE WATER POND LIMITING CONDITION FOR OPERATION 3.7.5 The standby nuclear service water pond (SNSWP) shall be OPERABLE with:

a.

A minimum USGS water datum, and level at or above elevation 570 feet Mean Sea Level, b.

An average water temperature of less than or equal to 86.5*F at

. elevation 540 feet in the SNSWP intake structure.

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

lA ION: (unghstm{2-) )

NWith the requirements of the above specification not satisfied, be in at least HOT' STANDBY _within 6-hours and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

SURVEILLANCE REQUIREMENTS 4.7.5 The SNSWP shall be determined OPERABLE:

a.

At least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months by verifying the water level to be within its limit, b.

At least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months during the months of July, August, and September by verifying the water temperature to be within its limit, and c.

At least once per 12 months by visually inspecting the SNSWP dam and verifying no abnormal degradation, erosion, or excessive seepage.

I f

JUL 181985 CATAWBA - UNITS 1 AND 2 3/4 7-12 00T 7 1985

Y PLANT SYSTEMS PRoopSggjgy 3/4.7.6 CONTROL ROOM AREA VENTILATION SYSTEM 1

LIMITING CONDITION FOR OPERATION ' i l

3.7.6 Two independent Control Room Area Ventilation Systems shall be OPERADLE.

. . -- T::_ ::: -

APPLICABILITY: ALL MODES" ' N ACTION: [ dol-fy i d 2. j x MODES 1, 2, 3 and 4:

s. . . . -

With one Control Room Area Ventilation System inoperable, restore the inoperable system to OPERABLE status within 7 days or be in at least HOT -

30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months . 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 STANDBY MODES 5 and 6:

a.

With one Control Room Area Ventilation System inoperable, restore the inoperable system to OPERABLE status within 7 days or initiate and maintain operation of the remaining OPERABLE Control Room Area Ventilation System with flow through the HEPA filters and carbon adsorbers.

b.

With both Control Room Area Ventilation Systems inoperable. or with the OPERABLE Control Room Area Ventilation System, required to be operating by ACTION a., not capable of being powered by an OPERABLE emergency power source, suspend all operations involving CORE ALTERATIONS or positive reactivity changes.

c. The provisions of Specification 3.0.4 are not applicable.

SURVEILLANCE REQUIREMENTS 4.7.6 Each Control Room Area Ventilation System shall be demonstrated OPERABLE:

! a. At least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months by verifying that the control' room air temperature is less than or equal to 90'F; ,

b.

At least once per 31 days on a STAGGERED TEST BASIS by 16ttiating, from the control room, flow through the HEPA filters and carbon adsorbers and verifying that the system operates for at least 10 continuous hours with the heaters operating; OCT 7 1985 CATAWBA - UNITS 1 AND 2 3/4 7-13

PLANT SYSTEMS 3/4.7.7 PR60F & ggyjgy g 4 AUXILIARY BUILDING FILTERED EXHAUST SYSTEM LIMITING CONDITION FOR OPERATION 3.7.7 The Auxiliary Building Filtered Exhaust System shall be OPERABLE.

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

ACTION:

With the Auxiliary Building Filtered Exhaust System inoperable, restore the inoperable system to OPERABLE status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or be in at least HOT 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months . 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 STANDBY SURVEILLANCE REQUIREMENTS 4.7.7 The Auxiliary Building Filtered Exhaust System shall be demonstrated OPERABLE:

a.

At least once per 31 days by initiating, from the control room, flow through the HEPA filters and carbon adsorbers and verifying that the system operates for at least'10 continuous hours with the heaters i operating; ~ ,

b. At least once per 18 months by:

1

1) Verifying that the cleanup system satisfies the in place penetration and bypass leakage testing acceptance criteria of less than 1% and uses the test procedure guidance itt-Regula-tory Positions C.5.a. C.5.c and C.5.d* of Regulatdry' Guide 1.52, Revision'2',' March 1978, and the system flow rate ' s /0',000 cfm i 10%z - '-9 6

2) Verifying, wit 11n 31 days after removal, that a labora> tory analysis of a \

dance witLReg/ representative carbon sample ulatory Position C.6.b of Regulatory Guide 1.52, obtained in accor-Revision 2, March 1978, meets the laboratory testing criteria of Regulatory Position C.6.a of Regulatory Guide 1.52, Revi-sion 2, March 1978, for a methyl iodide penetration of less than 1%; and

Purging of residual refrigerant is not mandatory.

CATAWBA - UNITS 1 AND 2 3/4 7-16 OCT 71985

l PLANT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued)

)

3) Verifying a system flow rate o 000 cfm 210%-: f7 r fa,rduring system operation when tested in accordance with'ANS rh510-1980.

c.

After every 720 hours0.00833 days 0.2 hours 0.00119 weeks 2.7396e-4 months of carbon adsorber operation, by verifying, within 31 days after removal, that a laboratory analysis of a representative carbon sample obtained in accordance with Regulatory Position C.6.b of Regulatory Guide 1.52, Revision 2, March 1978, meets the laboratory testing criteria of Regulatory Position.C.6.a of Regulatory Guide 1.52, Revision 2. March 1978, for a methyl iodide penetration of less than 1%;

d. At least once per 18 months by:

1) Verifying that the pressure drop across the combined HEPA

~ filters, carbon adsorber banks, and moisture separators of less than 8 inches Water Gauge while operating the system at a flow rate of 30,000 cfm + 10% per fan,

2) Verifying that the system starts on a Safety Injection test signal, and directs its exhaust flow through the HEPA filters and carbon adsorbers,

3) Verifying that the system maintains the ECCS pump room at a negative pressure relative to adjacent areas, 4). Verifying that the filter cooling bypass valves can be manually opened, and

5) Verifying that the heaters dissipate 40 t 4 kW.

e.

. After_ any structural maintenance on the filter housing or, after each complete or partial replacement of a HEPA filter bank, by verifying that the cleanup system satisfies the in place penetration and bypass leakage testing acceptance criteria of less than 1% in accordance with ANSI M510-1980 for a DOP test aerosol while operating the system at a flow rate of 30,000 cfm 210% per fan; f.

After any structural maintenance on the filter housing or, after each complete or partial replacement of a carbon adsorber bank, by verify-ing that the cleanup system satisfies the in place penetration and bypass leakage testing acceptance criteria of less than 1% in accord-ance with ANSI H510-1980 for a halogenated hydrocarbon refrigerant test gas while operating the system at a flow rate of 30,000 cfm 2 10% per fan; and g.

After any structural maintenance on the filter housing or, following painting, fire or chemical release in any ventilation zone communicat-ing with the system by verifying, within 31 days after removal, that a laboratory analysis of a representative carbon sample obtained in accordance with Regulatory Position C.6.b of Regulatory Guide 1.52, Revision 2, March 1978, meets the laboratory testing criteria of Regu-latory Position C.6.a of Regulatory Guide 1.52, Revision 2, March 1978, for a methyl iodide penetration of less than 1%.

CATAWBA - UNITS 1 AND 2 3/4 7-17 OCT 7 BB5

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

REFUELING OPERATIONS PROOF & REVIEW COPY 3/4.9.11 FUEL HANDLING VENTILATION EXHAUST SYSTEM LIMITINGCbNOITIONFOROPERATION 3.9.11 shall be OPERABLE.At least one train of the Fuel Handling Ventilation Exhaust System APPLICABILITY:

Whenever irradiated fuel is in the storage pool.

ACTION:

a.

With both trains of the Fuel Handling Ventilation Exhaust System

. inoperable, suspend all operations involving movement of fuel within a the storage pool or crane operation with loads over the storage pool 4

until the Fuel Handling Ventilation Exhaust System is restored to OPERABLE status.'

b.

The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.

SURVEILLANCE REQUIREMENTS 4.9.11.1 One train of the Fuel Handling Ventilation Exhaust System shall be determined to be operating and discharging through the HEPA filter and carbon adsorbers at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months whenever irradiated fuel is being moved in the storage pool and during crane operation with loads over the storage pool.

4.9.11.2 Both trains of the Fuel Handling Ventilation Exhaust System shall be demonstrated OPERABLE:

a.

At least once per 31 days by initiating, from the control room, 4

flow through the HEPA filters and carbon adsorbers and verifying

, that the system operates for at least 10 continuous hours with the heaters operating;

b. At least once per 18 months by:

1) Verifying that the cleanup system satisfies the in place penetration and bypass leakage testing acceptance criteria of less than 1% and uses the test procedure guidance in Regulatory Positions C.S.a. C.S.c, and C.S.d* of Regulatory Guide-1252, Revision-2, March 1978, and the system flow rate is'1f>r665 'cfm 110%) - Sr.;I

.33)30 j' O'

Purging of residual refrigerant is not mandatory.

i 1 $N CATAWBA - UNITS 1 AND 2 3/4 9-14 oCT i

_ _ _ _ - - - - - - - -------- ~~- -'

~ ~ ~

PROOF & REVIEW copy REFUELING OPERATIONS SURVEILLANCE REQUIREMENTS (Continued)

2) Verifying, within 31 days after removal, that a laboratory analysis of a representative carbon sample obtained in accor-dance with Regulatory Positions C.6.b of Regulatory Guide 1.52, Revision 2, March 1978, meets the laboratory testing criteria of Regulatory Position C.6.a of Regulatory Guide 1.52, Revision 2, March 1978, for a methyl iodide penetration o. less than 3; and -

3513o

3) Verifying a system flow rate of fa i10% [pT:5. during D

system operation when tested in-acco ance with' ANSI-N510'-1980.

c. After every 720 hours0.00833 days 0.2 hours 0.00119 weeks 2.7396e-4 months of carbon adsorber operation in any train by verifying, within 31 days after removal, that a laboratory analysis of a representative carbon sample obtained in accordance with Regula-

tory Position C.6.b of Regulatory Guide 1.52, Revision 2, March 1978, meets the laboratory testing criteria of Regulatory Position C.6.a of Regulatory Guide 1.52, Revision 2, March 1978, for a methyl iodide penetration of less than 1%.

d. At least once per 18 months for each train by:

1) Verifying that the pressure drop across the combined HEPA filters, carbon adsorber banks, and moisture separators is less than 8 inches Water Gauge while operating the system at a flow rate of 16,565 cfm i 10% per fan.

2) Verifying that the system maintains the spent fuel storage pool area at a negative pressure of greater than or equal to k inch Water Gauge relative to the outside anosphere during system operation,

3) Verifying that the filter cooling bypass valves can be manually opened, and

4) Verifying that the heaters dissipate 80 i 8 kW.

e. After any structural. maintenance on the filter housinq. or after each

~

complete or partial replacement'of' a HEPA filter bank in any train, by verifying that the cleanup system satisfies the in place penetra-tion and bypass leakage testing acceptance criteria of less than 1%

in accordance with ANSI N510-1980 for a DOP test aerosol while operat-ing the system at a flow rate of 16,565 cfm i 10% per fan ,

f. After any structural maintenance on f.he filter housina, or.vter each complete or partial replacement of a , carbon adsorber bank in any train, by verifying that the cleanup system satisfies the in place penetra-tion and bypass leakage testing acceptance criteria of less than 1%

in accordance with ANSI N510-1980 for a halogenated hydrocarbon refrig-erant test gas while operating the system at a flow rate of 16,565 cfm i 10% per fan; and CATAWBA - UNITS 1 AND 2 3/4 9-15 ocT

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I VICE PRESIDENT MA ER VICE PRESIDE NT DES 6GN VICE PRESIDENT MANAGER VICE PRESIDENT CONSTRUCTION CORPORATE QUALITY PROJECT CONTROL PRODUCTION

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TABLE 6.2-1 MINIMUM SHIFT CREW COMPOSITION POSITION NUMBER OF INDIVIDUALS REQUIRE 0 TO FILL POSITION Both Units in Both Units in- One Unit in Mode 1, 2J3' or';4 Mode 5 or 6 and Mode 1, 2, 3 or 4 or Defueled or }

One Unit in Mode 5,o/r 6,Defueled SS 1 SRO 1 1 1 (j None## 1 RO 3# 2# 3#

NEO 3# 3# 3#

STA 1 None 1

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Shift Supervisor with a Senior Operator' license -- " 't l' SRO -

Individual with a Senior Operator-license ).

RO -

Individual with an Operator lice'nse - " ' "r't 1 -

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NEO Nuclear Equipment Operator ( '

STA -

Shift Technical Advisor 'v '

i The Shift Crew Composition may be 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 to within the minimum requirements i

of Table 6.2-1. This provision does not permit any shift crew position to be-unmanned upon shift change due to an oncoming shift crewman being late or absent.

During any absence of the Shift Supervisor from the control room while the unit is in MODE 1, 2, 3, or 4, an individual (other than the Shift Technical Advisor *) with a valid Senier Operator ifcense 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, an individual with a valid Senior Operator license or Operator license shall be designated.,to assume the control room command function.

l

0n occasion when there is a need for both the Shift Supervisor and the SRO to be absent from the control room, the STA shall be allowed to assume the

control room command function and serve as the SRO in the control room provided that: (1) the Shift Supervisor is available to return to the control room within 10 minutes,- (2)- the -assumption of SRO duties by the STA be limited to periods not in' excess of 15' minutes duration and a total time not to exceed I hour during(any M shift, and (3) the STA has a Senior Operator license on the unit. -

' #At least one of the required individuals must be assigned to the designated position for each unit.

1. At least one licensed Senior Operator or licensed Senior Operator Limited to Fuel Handling must be present during CORE ALTERATIONS on either unit, who i has no other concurrent responsibilities.

CATAWBA - UNITS 1 AND 2 6-5 ggi iN

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ML20133Q002

Text

Dear Mr. Denton:

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