Text

(VCSNS) - Technical Specification Change - TSP 930011 Accident Monitoring Instrument
	ML18046A010
Person / Time
Site:	Summer
Issue date:	12/17/1993
From:	Skolds J; South Carolina Electric & Gas Co
To:	George Wunder; Document Control Desk, Office of Nuclear Reactor Regulation
References
	RC-93-0310 NUDOCS 9401030367
	Download: ML18046A010 (35)
	v • d • e

,,*

'*'_ J ,J.

6SCE&G A scnrm Company

South Carolina Electric & Gas Company P.O. Box 88 Jenkinsville, SC 29065 (803) 345-4040 e John L. Skolds Vice President Nuclear Operations December 17, 1993 Refer to: RC-93-0310 Document Control Desk U.S. Nuclear Regulatory Commission Washington, DC 20555 Attention: Mr. G. F. Wunder Gentlemen:

Subject:

VIRGIL C. SUMMER NUCLEAR STATION (VCSNS)

DOCKET NO. 50/395 OPERATING LICENSE NO NPF-12 TECHNICAL SPECIFICATION CHANGE - TSP 930011 ACCIDENT MONITORING INSTRUMENTATION In accordance with 10CFR50.90, South Carolina Electric & Gas Company (SCE&G) is submitting an amendment request to License NPF-12 to change the Technical Specifications (TS) for VCSNS. The proposed change is a general revision to the Accident Monitoring Instrumentation, TS 3/4.3.3.6, and associated Bases 3/4.3.3.6, and relocates the Hydrogen Monitors, TS 3/4.6.5.1, and the Reactor Building Area High Range Radiation Monitors, TS 3/4.3.3.1, Tables 3.3-6 and 4.3-3, item 1.c, into the Accident Monitoring TS. Accordingly, SCE&G withdraws the request made in the application dated July 22, 1992 (TSP 890005), to revise the Accident Monitoring Instrumentation.

The proposed change provides requirements for key plant variables consistent with VCSNS's accepted program on Revision 3, Regulatory Guide (RG) 1.97, Instrumentation for Light Water Cooled Nuclear Power Plants to Assess Plant and Environs Conditions During and Following an Accident.

The proposed TS change is consistent with NUREG-1431, Standard Technical Specifications for Westinghouse Plants, except for the Condensate Storage Tank (CST) Level and the Containment Isolation Valve Position Indication.

VCSNS CST Level is neither a Category 1 variable nor a key variable, based on the fact that the operator does not take any prescribed manual action based on CST level indication. Normally, the Emergency Feedwater (EFW) System is aligned to take suction from the CST; once its inventory is depleted, the EFW pump suction will automatically switch to the Service Water System.

Therefore, the CST Level does not provide primary information to the operator and does not meet the criteria of a key variable. For the Containment Isolation Valve (CIV) Position Indication, redundant isolation valves are provided for lines penetrating the containment, and only active valves have position indication. Check valves have no position indication and are specifically excluded by the Regulatory Guide.

Document Control Desk Letter TSP 930011 Page 2 of 2 The amendment request is contained in the following enclosures:

Enclosure 1 References Enclosure 2 Proposed TS Change Enclosure 3 Description and Safety Evaluation Enclosure 4 Determination of No Significant Hazards Consideration The proposed TS change has been reviewed and approved by the Plant Safety Review Committee and the Nuclear Safety Review Committee.

I declare that the statements and matters set forth herein are true and correct to the best of my knowledge, information, and belief.

Should you have any questions concerning this issue, please call Mr. Manuel W. Gutierrez at (803) 345-4392 at your convenience.

~John L. Sko 1ds MWG:lcd Enclosures c: O. W. Dixon (w/o Enclosures)

R.R. Mahan (w/o Enclosures)

R. J. White S. D. Ebneter NRC Resident Inspector J.B. Knotts Jr.

M. K. Batavia RTS (TSP 930011)

Central File System File (813.20)

NUCLEAR EXCELLENCE - A SUMMER TRADITION!

l ~

e Enclosure 1 to Document Control Desk Letter TSP 930011 Page 1 REFERENCES

1. South Carolina Electric & Gas Co. (SCE&G) letter ito NRC dated April 15, 1985 - 11 V. C. Summer Nuclear Station (VCSNS) - Generic Letter 82-33, Emergency Response Capability Supplement 1 to NUREG-0737 11

2. NRC letter to SCE&G dated June 18, 1986 - "Regulatory Guide 1.97 Request for Additional Information 11

3. SCE&G letter to NRC dated August 18, 1986 - VCSNS - 11 Regulatory Guide 1.97 Request for Additional Information 11

4. SCE&G letter to NRC dated October 31, 1986 - VCSNS - 11 Regulatory Guide 1.97 Request forAdditional Information 11

5. NRC letter to SCE&G dated November 13, 1987 - 11 Regulatory Guide 1.97 (TAC No.51137) 11

6. SCE&G letter to NRC dated February 16, 1988 - VCSNS - 11 Regulatory Guide 1.97 Open ltems 11

7. SCE&G letter to NRC dated May 20, 1988 - VCSNS - 11 Generic Letter 82-33, Regulatory Guide 1.97 11

8. NRC letter to SCE&G dated July 27, 1988 - 11 Safety Evaluation on Conformance to Regulatory Guide 1.97 (TAC No.51137) 11

9. SCE&G letter to NRC dated September 4, 1992 - 11 Instrumentation to Follow the Course of an Accident, Regulatory Guide 1.97 11

10. SCE&G letter to NRC dated September 14, 1992 - 11 Technical Specification Change - TSP 890005, Accident Monitoring Instrumentation 11

' ~ .

Enclosure 2 to Document Control Desk Letter TSP 930011 Page 1 PROPOSED TECHNICAL SPECIFICATION CHANGE - TSP 930011 VIRGIL C. SUMMER NUCLEAR STATION LIST OF AFFECTED PAGES Page INDEX Page VII 3/4 3-42 3/4 3-45 3/4 3-56 3/4 3-57 3/4 3-57a New Page 3/4 3-58 3/4 3-59 Deleted 3/4 3-60 Deleted 3/4 6-21 Deleted B 3/4 3-3 B 3/4 3-3a New Page B 3/4 3-3b New Page B 3/4 3-3c New Page B 3/4 3-3d New Page

~-.

INDEX LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REQUIREMENTS SECTION PAGE 3/4.6 CONTAINMENT SYSTEMS 3/4.6.1 PRIMARY CONTAINMENT Containment Integrity ................................... . 3/4 6-1 Con t a,' nment Leakage ..................................... . 3/4 6-2 Containment Air Locks ................................... . 3/4 6-4 Internal Pressure ....................................... . 3/4 6-6 Air Temperature ......................................... . 3/4 6-7 Containment Structural Integrity ........................ . 3/4 6-8 Containment Ventilation System ........................... . 3/4 6-11 3/4.6.2 DEPRESSURIZATION ANO COOLING SYSTEMS Reactor Building Spray System ............................ 1 3/4 6-12 Spray Additive System.................................... 3/4 6-13 Reactor Building Cooling System.......................... 3/4 6-14 3/4 6.3 PARTICULATE IODINE CLEANUP SYSTEM ....................... . 3/4 6-15 3/4. 6. 4 CONTAINMENT ISOLATION VALVES ............................ . 3/4 6-17 3/4. 6. 5 ~COMBUSTIBLE -~~S CONTROL . ,--------.-.,_

DELG.TE!) ~ g e n Monitors~-.~~~- ...................... ;.. 3/4 6-2~/ -'

. Electric Hydrogen Recombi ners. . . . . . . . . . . . . . . . . . . . . . . . . . . . 3/ 4 6-22 SUMMER-UNIT 1 VII

I **

TABLE 3.3-6 RADIATION MONITORING INSTRUMENTATION MINIMUM CHANNELS APPLICABLE ALARM/TRIP MEASUREMENT INSTRUMENT OPERABLE MODES SETPOINT RANGE ACTION

l. AREA MONITORS

a. Spent Fuel Pool Area (RM-GB) 1 * < 15 niR/hr 25

b. Reactor Building Manipulator Crane Area (RM-Gl7A or 1 6 < 1 R/hr 1 - 10 5 mr/hr 28 t)~La~~J!ild-i-nirArea ~ -= -c:: - ~ ~- - - - -

~-tgnnange RM-G7 and 2__.-- 1, 2, 3 ~ N/A 1x10*7' 1 U h r ~ O

.. High Range RM-Gl~ ~ ~ .,/1 - 10 7 R/hr ~

2. PROCESS MONITORS . . * .__,/

a. Spent Fuel Pool Exhaust -

Ventilation System (RM-A6) -5 µCi/cc

i. Gaseous Activity 1 ** < 1 x 10 10 - 10 6 cpm 27

{Kr-85) ii. Particulate Activity 1 ** N/A 10 - 106 cpm 27

b. Containment

i. Gaseous Activity

- Purge & Exhaust

~

(Tl

z Isolation (RM-A4) ii. Particulate and Gaseous 1 6 ~ 2 x background*** 10 - 106 cpm 28 e C,

Activity (RM-A2) - RCS 10 - 10 6 cpm 3:

(Tl

z Leakage Detection 1 1,2,3&4 N/A 26 10 - 106 cpm

~

.:z 0

C. Control Room Isolation (RM-Al) 1 ALL MODES -< 2 x background 29

With fuel in the .storage pool or building

- With irradiated fuel in the storage pool

- - Alarm/trip setpoint will be per the Operational Dose Calculation Manual when purge exhaust operations are in progress

I TABLE 4.3-3 (;,,.,

V, C

3 3

RADIATION MONITORING INSTRUMENTATION* SURVEILLANCE REQUIREMENTS rr,

,c ANALOG CHANNEL MODES FOR WHICH C

CHANNEL .CHANNEL OPERATIONAL SURVEILLANCE z INSTRUMENT CHECK CALIBRATION TE"ST IS REQUIRED t-t

~ l. AREA MONITORS

a. Spent Fuel Pool Area (RM-GB) s R M *

b. Reactor Building Manipulator s R M 6 C ne ea "(RM-G17A or RM-Gl7B)

Reactor Bu Range

~ 2.

a.

High Range PROCESS MONITORS Spent Fuel Pool Exhaust Area -

Ventilation System (RM-A6)

i. Gaseous Activity s R M **

w

11. Particulate Activity s R M **

-~

b. Containment w

i. Gaseous Activity I - Purge & Exhaust

~

c.,, Isolation (RM-A4) s R M 6 ii. Particulate and Gaseous Activity - RCS Leakage s R M 1, 2, 3 &4 Detection (RM-A2)

C. Control Room Isolation (RM-Al) s R M All MODES

i::- d. Noble tas Effluent Monitors 3

fTI (High Range) z C i. Main Plant Vent (RM-A13) s R M l, 2, 3 & 4 3

fTI ii. Main Steam Lines z (RM-Gl~A, B, C) s R M 1, 2, 3 & 4 z iii. Reactor Building Purge 0

Supply & Exhaust

\0 System (RM-A14) s R M 1, 2, 3 & 4

I ~- e e INSTRUMENTATION ACCIDENT MONITORING INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.3.6 *The accident monitoring instrumentation cha shall be OPERABLE.

APPLICABILITY: MODES 1, 2 and 3.

ACTION:

a.

3/4 3-56

V, C:

3: TABLE 3.3-10 3:

m

o ACCIDENT MONITORING INSTRUMENTATION C

....-I

z REQUIRED NO . MINIMUM I-' OF CHANNELS INSTRUMENT CHANNELS OPERABLE

l. Reactor Building Wide Range Pressure 2

2. Reactor Coolant Outlet Temperature - THOT (Wide Range) 2

3. Reactor Coolant Inlet Temperature - TCOLD (Wide Range) 2

4. Reactor Cpolant Pressure - Wide Range w

5. Pressurizer Water Level

~

6. Steam Line Pressure w

I generator 0,

-...J 7. Steam Generator Water Level - Wide 1/steam generator

8. Emergency Feedwater Flow 1/steam generator

9. Refueling Water Storage Tank 2

10. Boric Acid Tank Water 2/tank 1/tank

11. 2

12. 2

TABLE 3.3-10 (Continued)

ACCIDENT MONITORING INSTRUMENTATION C TOTAL z

-I OF INSTRUMENT CHANNELS

13. Reactor Building/RHR Sump Level 2

14. DELETED.

15. Condensate Storage Tank Level 16.

17. 1 pair w

'w

.i,.

I 18. NaOH Storage Tank Level l/1 00

19. Reactor Coolant System Subcool

2 1

20. 2/valve* 1/valve*

21. Pressurizer I/valve I/valve

22. Pressurizer 2/valve I/valve

23. 4/core 2/core

)::,,

quadrant quadrant 3

11) 0.

24. 2 3

11) rt

z 0

is closed per Specification 3.4.4.

OJ

(.n

TABLE 4.3-7 ACCIDENT MONITORING C

z

..... CHANNEL

-l

...... INSTRUMENT CALIBRATION

1. ~~eactor Building Wide Range Pressure

2. Reactor Coolant Outlet Temperature -

3. Reactor Coolant R ---~-*

4. Reactor Coolant Pressure - R

5. R w

~

w

6. Steam Line M R I

u, I.O 7. M R

8. M R M R M R e

11. Reactor Building Discharge Flow M R

TABLE 4.3-7 (continued)

ACCIDENT MONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTS C

z CHANNEL

...... INSTRUMENT CHECK I-'

12. Reactor Building Temperature M R

13. Reactor Building/RHR Sump level R l

e

14. DELETED.

15. Condensate Storage Tank Level

16. Reactor Building Cooling Unit Service u,.l Water Flow

~

w

17. Service Water Temperature - R O'I I Cooling Unit (Inlet and Disc 0

18. NaOH Storage Tank R

19. M R

20. M* R*

21. PORV M R Safety Valve M R

)::,,

3

23. In-Core Thermocouples M R ro a.

3

24. M R ro r+

z 0 the associated block valve is closed per Specification 3.4.4.

00 u,

'- . e CONTAINMENT SYSTEMS 3/4. 6. 5 COlllfs:TlllE GAS CONTROL HYDROGEN MONITORS LIMITING CONDITION FOR OPERATION 3.6.5. 1 Two independent containment APPLICABILITY: MODES 1 and 2.

ACTION:

a. With one hydrogen monitor OPERABLE status within 30 next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

b. With both hydrogen moni ors OPERABLE status withi next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

4.6.5. 1 Each hydrogen monitor shall be demonstrated OPERABLE by the performance \

of a CHANNEL CHECK at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , an ANALOG CHANNEL OPERATIONAL TEST at least once per 31 days, and at least once per 92 days on a STAGGERED TEST BASIS by performing a CHANNEL CALIBRATION using sample gas containing 19.8 +/-0.1 volume percent hydrogen, balance nitrogen.

ii ,t_s 3, ,)

SUMMER - UNIT 1 3/4 6-21 Amendment No.~

e INSTRUMENTATION BASES 3/4.3.3.3 SEISMIC INSTRUMENTATION r The OPERABILITY of the seismic instrumentation ensures that sufficient capability is available to promptly determine the magnitude of a seismic event and evaluate the response of those features important to safety. This capability is required to pe~mit comparison of the_measured response to that used in the design basis for the 11facility to determine if plant shutdown is required pursuant to Appendix A11 of 10 CFR Part 100. The instrumentation is consistent with the recommendations of Regulatory-Guide l."12, 11 Instrumentation for Earth-quakes,11 April 1974.

3/4.3.3.4 METEOROLOGICAL INSTRUMENTATION The OPERABILITY Of the meteorological instrumentation ensures that sufficient meteorological qata is available for estimating potential radiation doses to the public as a result of routine or accidental release of radioactive materials to the atmosphere. This capability is required to evaluate the need 1

for initiating protective measures to protect the health and safety of the public and is consistent with the recommendations of Regulatory Guide 1.23, "OnsHe Meteorological Programs, 11 February 1972.

3/4.3.3.5 REMOTE SHUTDOWN INSTRUMENTATION The OPERABILITY of the remote shutdown instrumentation ensures that sufficient capabHity is available to perm;t shutdown and maintenance of HOT STANDBY of the facility from locations outside of the control room. This capability is required in the event control room habitability is lost and is consistent with General Design Criteria 19 of 10 CFR 50.

SUMMER - UNIT 1 B 3/4 3-3 Amendment No. 79

J' '-

INDEX

=

LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REQUIREMENTS SECTION PAGE 3/4.6 CONTAINMENT SYSTEMS.

3/4.6.1 PRIMARY CONTAINMENT Containment Integrity . ...... ....... **** 3/4 6-1 Containment Leakage ............... **** 3/4 6-2 Containment Air Locks . . .. . . . . . . . . . . . . . . 3/4 6-4 Internal Pressure . . . . . .... . . .

. . . . . . . . . 3/4 6-6 Air Temperature ******* ... * * * * * * *

3/4 6-7 Containment Structural Integrity ** . . . . . . *

3/4 ~-8 Containment Ventilation System *** . . . . . . . . . . 3/4 6-11 3/4 6.2 DEPRESSURIZATION AND COOLING SYSTEMS Reactor Building Spray System . . . . . . . . . . . . . . 3/4 6-12 Spray Additive System *** . . . . . . . . . . . . . . 3/4 6-13 Reactor Building Cooling System . . . . . . . . . . . . 3/4 6-14 3/4.6.3 PARTICULATE IODINE CLEANUP SYSTEM . .......... 3/4 6-15 3/4 6.4 CONTAINMENT ISOLATION VALVES ** ..... .. .. 3/4 6-17 3/4 6.5 COMBUSTIBLE GAS CONTROL Electric Hydrogen Recombiners ... . . . . . . . . . . 3/4 6-22 SUMMER - UNIT 1 VII Amendment No.

TABLE 3.3-6 C

(/)

RADIATION MONITORING. INSTRUMENTATION 7" 3:

3:

r,;i

o MINIMUM C

z INSTRUMENT CHANNELS APPLICABLE ALARM/TRIP MEASUREMENT I-<

-I OPERABLE MODES SETPOINT RANGE ACTION I-'

L AREA MON !TORS

a. Spent Fuel Pool Area (RM-GS) 1 * < 15 mR/hr 10-l - 104 mR/hr 25

b. Reactor Building Manipulator Crane Area (RM-G17A or RM-Gl7B) 1 6 1 R/hr 1 - 105 mR/hr e

< 28 I

2. PROCESS MONITORS

-w

..i::,.

w I

a. Spent Fuel Pool Exhaust -

Ventilation System (RM-A6)

i. Gaseous Activity 1

..i::,.

N ** < 1 x l0-5 µCi /cc 10 - 106 cpm 27 (Kr-85) ii. Particulate Activity 1 ** N/A 10 - 106 cpm. 27

b. Containment

i. Gaseous Activity - Purge &

Exhaust Isolation (RM-A4) 1 6 < 2 x background*** 10 - 106 cpm 28 e

i:,,

~ ii. - Particulate and Gaseous z

Cl Activity (RM-A2) - 1 1, 2, 3 & 4 N/A 10 - 106 cpm 26 3:

n, RCS Leakage Detection z

-I z c. Control Room Isolation (RM-Al) 1 ALL MODES < 2 x background 10 - 106cpm 29 0

..i::,.

I.O

With fuel in the storage pool or building

- With irradiated fuel in the storage pool

- - Alarm/trip setpoint will be per the Operational Dose Calculation Manual when purge exhaust operations are in progress.

(/')

C

s:

n, ,...

o TABLE 4.3-3 C

z

...... RADIATION MONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTS

-I I-'

ANALOG CHANNEL MODES FOR WHICH CHANNEL CHANNEL OPERATIONAL SURVEILLANCE INSTRUMENT CHECK CALIBRATION TEST IS REQUIRED

1. AREA MON ITO RS

a. Spent Fuel Pool Area (RM-GB)

b. Reactor Building Manipulator Crane Area (RM-G17A or RM-Gl7B) s s

R R

M M

6 e

2. PROCESS MONITORS

a. Spent Fuel Pool Exhaust Area -

Ventilation System (RM-A6)

-w

.i::,,

w I

.i::,,

i. Gaseous Activity ii. Particulate Activity

b. Containment

i. Gaseous Activity s

s R

R M

M (J1

- Purge & Exhaust Isolation (RM-A4) s R M 6 ii. Particulate and Gaseous Activity - RCS Leakage s R M 1, 2, 3 &4 Detection (RM-A2) s

c. Control Room Isolation (RM-Al)

d. Noble Gas Effluent Monitors (High Range)

R M All MODES e

i. Main Plant Vent (RM-Al3) s R M 1, 2, 3 & 4 ii. Main Steam Lines

i:,,

3 (RM-Gl9A, B, C) s R M 1, 2, 3 & 4 CD

I iii. Reactor Building Purge 0.

3 Supply & Exhaust CD

I

('T System (RM-A14) s R M 1, 2, 3 & 4

z 0

With fuel in the storage pool or building

.i::,,

I.O

- With irradiated fuel in the storage pool

/

INSTRUMENTATION ACCIDENT MONITORING INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.3.6 The accident monitoring instrumentation channels shown in Table 3.3-10 shall be OPERABLE.

APPLICABILITY MODES 1, 2, and 3.

ACTION:

a. With the number of OPERABLE accident monitoring channels less than the Required Number of Channels shown on Table 3.3-10, either restore the inoperable channel(s) to OPERABLE status within 30 days or submit a Special Report within the following 14 days from the time the action is required. The report shall outline the preplanned alternate method of monitoring, the cause of the inoperability, and the plans and schedule for restoring the instrumentation channels to operable status.

b.l With the number of OPERABLE Reactor Building radiation monitoring channels less than the Minimum Channels Operable requirement of Table 3.3-10, either restore the inoperable channel(s) to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , or:

i) Initiate the preplanned alternate method of monitoring the appropriate parameter(s), and ii) Submit a Special Report to the Commission pursuant to Specification 6.9.2 within 14 days following the event outlining the action taken, the cause of the inoperability, and the plans and schedule for restoring the system to OPERABLE status.

b.2 With the number of Hydrogen monitoring channels less than the Minimum Channels Operable requirement of Table 3.3-10, restore at least one monitor 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 .

b.3 With the number of OPERABLE accident monitoring channels less than the Minimum Channels Operable requirement of Table 3.3-10, either restore the inoperable channels to OPERABLE status within 7 days or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

c. The provisions of Specification 3.0.4 are not applicable.

SURVEILLANCE REQUIREMENTS 4.3.3.6 Each accident monitoring instrumentation channel shall be demonstrated OPERABLE by performing a monthly CHANNEL CHECK and a CHANNEL CALIBRATION every refueling outage. The Reactor Building Radiation Level Instrumentation CHANNEL CALIBRATION may consist of an electronic calibration of the channel, not including the detector, for the range decades above lOR/hr and a single point calibration of the detector below lOR/hr with an installed or portable gamma source.

SUMMER - UNIT 1 3/4 3-56 Amendment No.

TABLE 3.3-10 C:

z ACCIDENT MONITORING INSTRUMENTATION

-I REQUIRED MINIMUM INSTRUMENT NO. OF CHANNELS CHANNELS OPERABLE

1. Reactor Building Pressure - Narrow Range 2 1 Instrument Loop/Indicator:

Channel D IPT-951/IPI-951 Channel B IPT-952/IPI-952

2. Reactor Building Pressure - Wide Range 2 1 Instrument Loop/Indicator:

Channel D IPT-954A/IPI-954A Channel E IPT-954B/IPI-954B w

......... 3. Reactor Building Radiation Level - High Range 2 1

-i::::.. Instrument Loop/Indicator:

w I

Channel A RMG-18 Ui

-...J Channel B RMG-7

4. Reactor Building Hydrogen Concentration 2 1 Instrument Loop/Indicator:

Channel A IAE-8263A/ICI-8257 Channel B IAE-8263B/ICI-8258

5. Reactor Building/RHR Sump Level 2 1 Instrument Loop/Indicator:

Channel A ILT-1969/ILI-1969 Channel B ILT-1970/ILI-1970

6. Reactor Coolant Outlet Temperature - THot- Wide Range 2 1 J::,

Instrument Loop/Indicator:

3 (D.

Channel A ITE-413/ITI-413

s 0..

Channel A ITE-423/ITI-423 3

(D Channel E ITE-433/ITR-413

s c-+ 7. Reactor Coolant Inlet Temperature - TCold - Wide Range 2 1 z Instrument/Loop Indicator:

0 Channel E ITE-410/ITI-410 Channel E ITE-420/ITI-420 Channel E ITE-430/ITR-410

(/)

C 3:

3:

rri ...

0 TABLE 3.3-10 (continued)

C z ACCIDENT MONITORING INSTRUMENTATION

-I 1--'

REQUIRED MINIMUM INSTRUMENT NO. OF CHANNELS CHANNELS OPERABLE

8. Reactor Coolant Pressure - Wide Range 2 1 Instrument Loop/Indicator:

Channel E IPT-402/IPI-402 Channel A_ IPT-403/IPI-403

9. Pressurizer Water Level 2 1 Instrument Loop/Indicator:

Channel A ILT-459/ILI-459A Channel D ILT-460/ILI-460 w

Channel B ILT-461/ILI-461

..j:::,

w 10. Reactor Coolant System Subcooling Margin 2 1 I

(.]"1 Instrument Loop/Indicator:

"'-J Sl,l Channel A ITM-499A Channel B ITM-499B

11. Reactor Vessel Level 2 1 Instrument Loop/Indicator:

Channel A ILT-1311/ILI-1311, ILT-1312/ILI-1312 Channel B ILT-1321/ILI-1321, ILT-1322/ILI-1322

12. Core Exit Temperature 4/core 2/core Instrument Loop/Indicator: quadrant/ quadrant/

Channel A Channel B channel channel ITEs 2, 4, 9, 12, 13, ITEs 1, 3, 5, 6, 7, 15, 19, 21, 22, 23, 24, 8, 10, 11, 14, 16, 17,

)::, 25, 26, 27, 28, 29, 31, 18, 20, 30, 34, 36, 37, 3

(D 32, 33, 35, 39, 41, 42, 38, 40, 43, 44, 48, 49,

s 45, 46, 47 50, 51 0.

3 (D (Primary display is the plant computer)

s (Backup displays are ITM 499 A&B) c+

z

.0 13. Neutron Flux 2 1 Instrument Loop/Indicator:

Channel 1 INI-35 Channel 2 INI-36

(/)

C 3:

3:

rr,

a TABLE 3.3-10 (continued)

C z

ACCIDENT MONITORING INSTRUMENTATION

-l I--'

REQUIRED MINIMUM INSTRUMENT NO. OF CHANNELS CHANNELS OPERABLE

14. Steam Line Pressure 2/stm. gen. 1/stm. gen.

Instrument Loop/Indicator:

SG A IPTs-474, 475, 476/IPis-474, 475, 476 SG B IPTs-484, 485, 486/IPis-484, 485, 486 e SG C IPTs-494, 495, 496/IPis-494, 495, 496

15. Steam Generator Water Level - Wide Range 1/stm. gen. 1/stm. gen.

Instrument Loop/Indicator:

SG A ILT-477 /ILl-477 SG B ILT-487 /ILl-487 w

SG C ILT-497 /ILl-497

..i::,.

w 16. Steam Generator Water Level - Narrow Range 2/stm. gen. 1/stm. gen.

(Jl I Instrument Loop/Indicator:

CX)

SG A ILTs 474, 475, 476/ILis 474, 475, 476 SG B ILTs 484, 485, 486/ILis 484, 485, 486 SG C ILTs 494, 495, 496/ILis 494, 495, 496

17. Emergency Feedwater Flow 2/stm. gen. 1/stm. gen.

Instrument Loop/Indicator:

Channel A SG A IFT-3561/IFI-3561 SG B IFT-3571/IFI-3571 SG C IFT-3581/IFI-3581 Channel B SG A IFT-3561A/IFI-3561B

)::,

3 SG B IFT-3571A/IFl-3571B (1)

l SG C IFT-3581A/IFl-3581B 0.

3 (1) 18. Refueling Water Storage Tank Level 2 1

l rt- Instrument Loop/Indicator:

z Channel A ILT-990/ILl-990 0

Channel B ILT-992/ILI-992 CX)

(Jl

THIS PAGE LEFT BLANK INTENTIONALLY.

Pages 3/4 3-59 and 3/4 3-60 have been deleted.

SUMMER - UNIT 1 3/4 3-59 Amendment No.

This page left blank intentionally.

SUMMER - UNIT 1 3/4 6-21 Amendment No. 3, 4, 25

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e INSTRUMENTATION BASES.

3/4.3.3.3 SEISMIC INSTRUMENTATION The OPERABILITY of the seismic instrumentation ensures that sufficient capability is available to promptly determine the magnitude of a seismic event and evaluate the response of those features important to safety. This capability is required to permit comparison of the measured response to that used in the design basis for the facility to determine if plant shutdown is required pursuant to Appendix 11 A11 of 10 CFR Part 100. The instrumentation is consistent with the recommendations of Regulatory Guide 1.12, "Instrumentation for Earth-quakes," April 1974.

3/4.3.3.4 METEOROLOGICAL INSTRUMENTATION The OPERABILITY of the meteorological instrumentation ensures that

~ufficient meteorological data is available for estimating potential radiation doses to the public as a.result of routine or accidental release of radioactive materials to the atmosphere. This capability is required to evaluate the need for initiating protective measures to protect the health and safety of the public and is consistent with the recommendations of Regulatory Guide 1.23, 11 0nsite Meteorological Programs," February 1972.

3/4.3.3.5 REMOTE SHUTDOWN INSTRUMENTATION The OPERABILITY of the remote shutdown instrumentation ensures that sufficient capability is available to permit shutdown and maintenance of HOT STANDBY of the facility from locations outside of the control room. This capability is required in the event control room habitability*is lost and is consistent with General Design Criteria 19 of 10 CFR 50.

3/4.3.3.6 ACCIDENT MONITORING INSTRUMENTATION

The PAM Instrumentation LCO provides OPERABILITY requirements for Regulatory Guide 1.97 Type A monitors, which provide information required to perform certain manual actions specified in the Emergency Operating Procedures. These manual actions ensure that a system can accomplish its safety function and are credited in the safety analyses. Additionally, this LCO addresses Regulatory Guide 1.97 instruments that have been designated Category I, non-Type A.

The OPERABILITY of the PAM instrumentation ensures there is sufficient information available on selected unit parameters to monitor and assess unit status following an accident.

LCO 3.3.3.6 requires two OPERABLE channels for most Functions. Two OPERABLE channels ensure no single failure prevents operators from getting the information necessary for them to determine the safety status of the unit, and to bring the unit to and maintain it in a safe condition following an accident.

Furthermore, OPERABILITY of two channels allows a CHANNEL CHECK during the post accident phase to confirm the validity of displayed information.

SUMMER - UN IT 1 B 3/4 3-3 Amendment No. 79

INSTRUMENTATION BASES ACCIDENT MONITORING INSTRUMENTATION (Continued)

Type A and Category I variables are required to meet Regulatory Guide 1.97 Category I design and qualification requirements for seismic and environmental qualification, single failure criterion, utilization of emergency standby power, immediately accessible display, continuous readout, and recording of display.

The following are discussions of specified instrument functions listed in Table 3.3-10.

1. & 2. Reactor Building Pressure Reactor Building Pressure is provided for verification of RCS and containment OPERABILITY. Reactor Building Pressure is used to verify closure of main steam isolation valves (MSIVs), and containment spray Phase B isolation. Other manual actions based on Reactor Building Pressure include: stopping the RCPs, stopping containment spray pumps, and starting RHR pumps. Reactor Building Pressure indications are also required to calculate reactor vessel vent times.

3. Reactor Building Radiation Level Reactor Building Radiation Level is provided to monitor the potential of significant radiation releases and to provide release assessment for use by operators in determining the need to invoke site emergency'plans. Reactor Building Radiation Level is used to determine if a high energy line break (HELB) has occurred and whether the event is inside or outside of containment.

4. Reactor Building Hydrogen Concentration Reactor Building Hydrogen Concentration Monitors are provided to detect high hydrogen concentration conditions that represent a potential for containment breach from a hydrogen explosion. This variable is also important in verifying the adequacy of mitigating actions. Reactor Building Hydrogen concentration *is used by the operator to calculate reactor vessel vent time and is monitored as a criterion for continuing vessel venting when attempting to collapse voids.

5. Reactor Building/RHR Sump Water Level (Wide Range)

Reactor Building/RHR Sump Water Level is provided for verification and long term surveillance of RCS integrity. Reactor Building/RHR Sump Water Level is used to determine: containment sump level accident diagnosis; when to begin the recirculation procedure; and whether to terminate SI, if still in progress.

6. & 7. Reactor Coolant System (RCS) Hot and Cold Leg Temperatures RCS Hot and Cold Leg Temperatures variables provide verification of core cooling

and long term RCS surveillance. In addition, RCS cold leg temperature is used in

'*conjunction with RCS hot leg*temperature to verify the unit conditions necessary to establish natural circulation in the RCS.

SUMMER - UN IT 1 B 3/4 3-3a . Amendment No.

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e INSTRUMENTATIO't~

BASES ACCIDENT MONITORING INSTRUMENTATION (Continued)

8. Reactor Coolant Pressure RCS pressure provides verification of core cooling and RCS integrity long term surveillance. RCS pressure is used to verify delivery of SI flow to RCS from at least one train when the RCS pressure is below the pump shutoff head. RCS pressure is also used to verify closure of manually closed spray line valves and pressurizer power operated relief valves (PORVs). RCS pressure can be used:

to determine whether to terminate actuated SI or to reinitiate stopped Sl; to determine when to reset SI and shut off *1ow head SI; to manually restart low head SI; as reactor coolant pump (RCP) trip criteria; and to make a determination on the nature of the accident in progress and where to go next in the procedure.

RCS pressure is also related to three decisions about depressurization. They are: to determine whether to proceed with primary system depressurization; to verify termination of depressurization; and to determine whether to close accumulator isolation valves during a controlled cooldown/depressurization.

A final use of RCS pressure is to determine whether to operate the pressurizer heaters. RCS pressure-is used by the operator to monitor the cooldown of the RCS following a steam generator tube rupture (SGTR) or small break LOCA.

Operator actions to maintain a controlled cooldown, such as adjusting steam generator (SG) pressure or level, would use this indication. Furthermore, RCS pressure is one factor that may be used in decisions to ~erminate RCP operation.

9. Pressurizer Level Pressurizer Level is used to determine whether to terminate SI, if still in progress, or to reinitiate SI if it has been stopped. Knowledge of pressurizer water level is also used to verify the unit conditions necessary to establish natural circulation in the RCS and to verify that the unit is maintained in a safe shutdown condition.

10. Reactor Coolant System Subcooling Margin RCS hot and cold leg temperatures are used to determine RCS subcooling margin.

RCS subcooling margin will allow termination of safety injection (SI), if still in progress, or reinitiation of SI if it has been stopped. RCS subcooling margin is also used for unit stabilization and cooldown control.

11. Reactor Vessel Level Reactor Vessel Level is provided for verification and long term surveillance of core cooling. It is also used for accident diagnosis and to determine reactor coolant inventory adequacy.

Reactor Vessel Level Monitoring provides direct measurement of collapsed liquid level above the fuel alignment plate. Collapsed level represents the amount of liquid mass that is in the reactor vessel above the core. Measurement of collapsed water level is selected because it is a direct indication of the water inventory.

SUMMER - UN IT 1 B 3/4 3-3b Amendment No.

INSTRUMENTATION BASES ACCIDENT MONITORING INSTRUMENTATION {Continued)

12. Core Exit Temperature Core Exit Temperature is provided for verification and long term surveillance*

of core cooling. Core Exit Temperature is used to determine whether to terminate SI, if still in progress, or to reinitiate SI if it has been stopped. Core Exit Temperature is also used for unit stabilization and cooldown control.

Two OPERABLE channels of Core Exit Temperature, in each quadrant, provide indication of radial distribution of coolant temperature rise across representative regions of the core. Power distribution symmetry was considered in determining the specific number and locations provided for diagnosis of local core problems. Two randomly selected thermocouples are not sufficient to meet the two thermocouples per channel requirement in any quadrant. The two thermocouples in each channel must meet the additional requirement that one is located near the center of the core and the other near the core perimeter, such that the pair of Core Exit Temperatures indicate the radial temperature gradient across their core quadrant.

Two sets of two thermocouples ensure a single failure will not disable the ability to determine the radial temperature gradient.

13. Neutron Flux Neutron Flux indication is provided to verify reactor shutdown. Neutron flux is used for accident diagnosis, verification of subcriticality, and diagnosis of positive reactivity insertion.

14. Steam Line Pressure Steam Line Pressure is used to: identify and isolate a faulted steam generator; maintain an adequate reactor heat sink; verify that EFW to steam generator '

associated with pipe rupture is isolated; and monitor secondary side steam pressure to: verify operation of pressure control steam dump system, monitor RCS cooldown rate, and maintain plant in col.d shutdown condition.

SUMMER - UNIT 1 B 3/4 3-3c Amendment No.

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4 I -
e Enclosure 4 to Document Control Desk Letter TSP 930011 Page 1 PROPOSED TECHNICAL SPECIFICATION CHANGE - TSP-930011 VIRGIL C. SUMMER NUCLEAR STATION DETERMINATION OF NO SIGNIFICANT HAZARDS CONSIDERATION DESCRIPTION OF AMENDMENT REQUEST SCE&G proposes to modify the VCSNS TS to revise TS 3/4.3.3.6, 11 Accident Monitoring Instrumentation, 11 and associated Bases 3/4.3.3.6. This change will reflect the plant variables (key variables) that provide primary information required to permit control room operators to take specified manually controlled actions (for which no automatic control is provided) after initial stages of an accident and that are required for safety systems to accomplish their safety function for design basis accident events.
The instrumentation, to be included in Table 3.3-10, is designated type A category 1, except for the Subcooling Margin Monitor which is category 2 but meets the intent of category 1, and non-type A category 1. This designation is in accordance with the guidance given in Regulatory Guide (RG) 1.97, revision 3, and SCE&G submittal of April 15, 1985 found acceptable by the NRC in its Safety Evaluation Reports dated November 13, 1987, and July 27, 1988.
The proposed TS change is consistent with NUREG-1431, Standard Technical Specifications for Westinghouse Plants. The following instrumentation shall be included in Table 3.3-10:
1. Reactor Building Pressure - Narrow Range
2. Reactor Building Pressure - Wide Range
3. Reactor Building Radiation Level - High Range
4. Reactor Building H2 Concentration
5. Reactor Building/RHR Sump Level
6. Reactor Coolant Outlet Temperature -THot - Wide Range
7. Reactor Coolant Inlet Temperature - Tcold - Wide Range
8. Reactor Coolant Pressure - Wide Range
9. Pressurizer Water Level
10. Reactor Coolant System Subcooling Margin
11. Reactor Vessel Water Level
12. Core Exit Temperature
13. Neutron Flux
14. Steam Line Pressure
15. Steam Generator Water Level - Wide Range
16. Steam Generator Water Level - Narrow Range
17. Emergency Feedwater Flow
18. Refueling Water Storage Tank Level
> I ...
e Enclosure 4 to Document Control Desk Letter TSP 930011 Page 2 The following non-Category 1 instrumentation shall be deleted from Table 3.3-10:
1. Boric Acid Tank Water Level
2. Reactor Building Spray Pump Discharge Flow
3. Reactor Building Temperature
4. Condensate Storage Tank Level
5. Reactor Building Cooling Unit Service Water Flow
6. Service Water Temperature-Reactor Building Cooling Unit (Inlet and Discharge)
7. Pressurizer PORV Position Indicator
8. Pressurizer PORV Block Valve Position Indicator
9. Pressurizer Safety Valve Position Indicator
10. Sodium Hydroxide Storage Tank Level Table 4.3-7 shall be deleted.
The TS for the Reactor Building Area High Range Radiation Monitors, TS 3/4.3.3.1, Table 3.3-6 and 4.3-3, Item 1.c, and the Hydrogen Monitors, TS 3/4.6.5.1, have been relocated into this TS in order to have a consistent set of technical specifications.
The allowable outage time for the accident monitoring instruments has been changed from 7 to 30 days (for conditions in which the number of OPERABLE accident monitoring channels is less than the Required Number of Channels) and from 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months to 7 days (for conditions in which the number of OPERABLE accident monitoring channels is less than the Minimum Channels Operable),
requiring a reduction to mode 3 (HOT STANDBY) within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and then to mode 4 (HOT SHUTDOWN) within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .
The mode APPLICABILITY for the Reactor Building Hydrogen Monitors was changed to include mode 3; the Reactor Building Area High Range Radiation Monitor was changed to delete mode 4.
Administrative changes were made to TS 3/4.3.3.6, Table 3.3-10.
BASIS FOR DETERMINATION OF NO SIGNIFICANT HAZARDS CONSIDERATION SCE&G has evaluated the proposed TS change and has determined that it does not represent a significant hazards consideration, based on the criteria established in 10 CFR 50.92(c). Operation of VCSNS in accordance with the proposed action will not:
') . e Enclosure 4 to Document Control Desk Letter TSP 930011 Page 3 (1) Involve a significant increase in the probability or the consequences of an accident previously evaluated.
Regulatory Guide 1.97 furnishes standards acceptable to the NRC for providing instrumentation to monitor plant variables and systems during and following an accident. The purpose of the accident monitoring instrumentation is to display plant variables that.provide information .
required by the control room operators for manual actions and long term recovery. Determination of variable types and category designations for VCSNS was accomplished from a review of the Emergency Response Guidelines (ERGs), the Final Safety Analysis Report, and the Westinghouse Owners Group (WOG) ERGs. The WOG ERGs were used at VCSNS as a basis for the Emergency Response Procedures. Operability of the instruments used for accident monitoring ensures there is sufficient information available on selected plant parameters to monitor plant status during and following an accident. The changes proposed do not affect components that can cause an accident. The increase in allowable outage times from 7 to 30 days or from 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months to 7 days does not significantly affect the consequences of an event previously evaluated. The channel redundancy and the relatively short outage times, coupled with the low probability of an event requiring accident monitoring instrumentation during this interval, ensure that sufficient information is available for operator manual actions. The condition of the plant in either HOT STANDBY or HOT SHUTDOWN, the first stage of the plant shutdown process, has no impact on the assumptions made in the accident analysis.
The change in mode applicability for the Reactor Building Area High Range Radiation Monitors to include modes 1, 2, and 3, but exclude mode 4, is based on the usage of these monitors which is to indicate a significant degradation of the reactor coolant pressure boundary.
These monitors do not initiate any automatic mitigation system and are solely required to be operable to provide indication which in conjunction with other operator actions will aid in mitigating the consequences of design basis accidents. Design basis accident sequences which may create a significant degradation of the reactor coolant pressure boundary are not postulated to occur during mode 4.
Therefore, the proposed change does not increase the probability or consequences of any accident previously evaluated.
(2) Create the possibility of a new or different kind of accident from any previously analyzed.
The proposed change is consistent with the requirements of RG 1.97.
The accident monitoring instrumentation will make available reliable information to plant control room operators to mitigate
to. Document Control Desk Letter TSP 930011 Page 4 the consequences of a design basis accident. The first stages *of plant shutdown, HOT STANDBY and HOT SHUTDOWN, are plant modes for which VCSNS has been analyzed. Since no plant configuration changes or changes to the mode of operation of equipment, systems, and components are introduced by the proposed technical specification, no new failure modes or accident sequences are instituted. Therefore, the changes proposed do not create the possibility of a new or different kind of accident from any previously analyzed.
(3) Involve a significant reduction in a margin of safety.
The inclusion of category 1, type A or B, instrumentation in the TS provides assurance that adequate information is available to the operators to maintain VCSNS in a safe condition during and following a design basis accident. Accomplishment of specific manual action by the control room operators is enhanced due to the availability and reliability of the indications. The proposed changes do not affect the design or operation of safety related components relied upon to automatically mitigate the consequences of a design basis event. The proposed change from HOT SHUTDOWN to HOT STANDBY as the first stage of plant shutdown will not affect the design or operation of any safety related system or component. Therefore, the changes proposed would not involve a reduction in any margin of safety.

RC-93-0310, (VCSNS) - Technical Specification Change - TSP 930011 Accident Monitoring Instrument

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RC-93-0310, (VCSNS) - Technical Specification Change - TSP 930011 Accident Monitoring Instrument

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