ML20100B947

Rev 21 of CPSES Units 1 & 2 Technical Requirements Manual

ML20100B947
Person / Time
Site:	Comanche Peak
Issue date:	01/24/1996
From:	TEXAS UTILITIES ELECTRIC CO. (TU ELECTRIC)
To:
Shared Package
ML20100B946	List: ML20100B947 TXX-9602, Forwards Rev 21 of CPSES Units 1 & 2 Technical Requirements Manual
References
PROC-960124, NUDOCS 9601290321
Download: ML20100B947 (16)

Text

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COMANCHE PEAK STEAM ELECTRIC STATION UNITS 1 & 2 TECHNICAL REQUIREMENTS MANUAL-INSTRUCTION SHEET (Page 1 of 1)

The following instructional information and checklist is being furnished to help insert Revision 21 into the Comanche Peak Steam Electric Station TRM. A description of this revision is provided in TXX-96027, dated January 24, 1996.

Discard the old sheets and insert the new sheets, as listed below.

Remove Insert I

Section 1 1-2 1-2 1-3 1-3 1-6 1-6 1-7 1-7 i

1-8 1-8 1-9 1-9 1-11 1-11 Section 2 2-3 2-3 2-7 2-7 2-9 2-9 2-25 2-25 List of Effective Paaes EPL-1 through EPL-4 EPL-1 thru EPL-4 NOTE: Please complete the entry for insertion of Revison 21 on the " Record of Changes" form located at the beginning of the TRM.

l 9601290321 960124 PDR ADOCK 05000445 P

PDR

o CPSES/TRM TECHNICAL REQUIREMENT 1.1 Table 1.1.1 REACTOR TRIP SYSTEM INSTRUMENTATION RESPONSE TIMES FUNCTIONAL UNIT RESPONSE TIME

'1.

Manual Reactor Trip N.A.

2. ' Power Range. Neutron Flux 5 0.5 second*

3.

Power Range. Neutron Flux High Positive Rate N.A.

4.

Not Used 19 5.

Intermediate Range. Neutron Flux N.A.

6.

Source Range. Neutron Flux N.A.

21 i

7.

Overtemperature N-16 5 7 seconds *#

8.

Overpower N-16 5 7 seconds *#

9.

Pressurizer Pressure-Low s 2 seconds

10. Pressurizer Pressure-High 5 2 seconds 1

11. Pressurizer Water Level-High N.A,

)

• Neutron / gamma detectors are exempt from response time testing. Response time of 1

the neutron / gamma flux signal portion of the channel shall be measured from detector output or input of first electronic component in a channel.

1. Response time includes the thermal well response time.

COMANCHE PEAK - UNITS 1 AND 2 1-2 Revision 21 January 24, 1996

,.ms,

,7

u, CPSES/TRM TECHNICAL REQUIREMENT 1.1 (continued)

Table 1.1.1 (continued)

REACTOR TRIP SYSTEM INSTRUMENTATION RESPONSE TIMES FUNCTIONAL UNIT RESPONSE TIME

12. Reactor Coolant Flow-Low a.

Single Loop (Above P-8) s 1 second b.

Two Loops (Above P-7 and below P-8) 5 1 second

13. Steam Generator Water Level--Low-Low 5 2 seconds

14. Undervoltage - Reactor Coolant Pumps 5 1.1 seconds

• 21

15. Underfrequency - Reactor Coolant Pumps 5 0.6 second

16. Turbine Trip a.

Low Fluid Oil Pressure N.A.

i b.

Turbine Stop Valve Closure N.A.

17. Safety Injection Input from ESFAS N.A.

18. Reactor Trip System Interlocks N.A.

j

19. Reactor Trip Breakers N.A.

20. Automatic Trip and Interlock Logic N.A.

An additional of 0.4 seconds maximum calculated voltage decay time from the 21 opening of RCP breaker until voltage reaches the undervoltage set-point provides an overall time s 1.5 seconds.

BASES 1.1 REACTOR TRIP SYSTEM RESPONSE TIMES The bases for the Reactor Trip System are contained in the CPSES Technical i

Specifications. The measurement of response time at the specified frequencies provides assurance that the Reactor trip actuation associated with each channel i

is completed within the time limit assumed in the safety analyses. No credit was l

taken in the analyses for those channels with response times indicated as not applicable. Response time may be demonstrated by any series of sequential, overlapping, or total channel test measurements provided that such tests demonstrate the total channel response time as defined. Sensor response time verification may be demonstrated by either:

(1) in place, onsite. or offsite test measurements, or (2) utilizing replacement sensors with certified response time.

COMANCHE PEAK - UNITS 1 AND 2 1-3 Revision 21 January 24, 1996

CPSES/TRM TECHNICAL REQUIREMENT 1.2 (continued)

TABLE 1.2.1 (continued)

ENGINEERED SAFETY FEATURES RESPONSE TIMES INITIATION SIGNAL AND FUNCTION RESPONSE TIME IN SECONDS 2.

Containment Fressure--High-1 a.

Safety Injection (ECCS) 527(1,5a 10)/ 27(4,5b.10) 21 b.

Reactor Trip 52 un c.

Feedwater Isolation 57 d.

Phase "A" Isolation 517(2)/27II' e.

Containment Ventilation Isolation N.A.

III f.

Motor-Driven Auxiliary Feedwater 560 21 i

g.

Station Service Water N.A.

i h.

Component Cooling Water N.A.

1.

Essential Ventilation Systems N.A.

j.

Emergency Diesel Generator 5 12 Operation k.

Turbine Trip N.A.

1.

Control Room Emergency Recirculation N.A.

II'7) m.

Containment Spray Pump 532 11 COMANCHE PEAK - UNITS 1 AND 2 1-6 Revision 21 January 24. 1996

+

CPSES/TRM TECHNICAL REQUIREMENT 1.2 (continued)

TABLE 1.2.1 (continued)

ENGINEERED SAFETY FEATURES RESPONSE TIMES INITIATION SIGNAL AND FUNCTION RESPONSE TIME IN SECONDS 3.

Pressurizer Pressure--Low a.

Safety Injection (ECCS) 527 (1.5a.10)/ 27 (4.5.10b) 21 b.

Reactor Trip 5 2 ou c.

Feedwater Isolation s7 d.

Phase "A" Isolation 5 17 (2)/27 III e.

Containment Ventilation Isolation 5 5 (6) 9 II) f.

Motor-Driven Auxiliary Feedwater s 60 21 9

Station Service Water N.A.

h.

Component Cooling Water N.A.

1.

Essential Ventilation Systems N.A.

J.

Emergency Diesel Generator Operation s 12 k.

Turbine Trip N.A.

1.

Control Room Emergency Recirculation N.A.

m.

Containment Spray Pump N.A.

9 i

l COMANCHE PEAK - UNITS 1 AND 2 1-7 Revision 21 January 24, 1996

i CPSES/TRM TECHNICAL REQUIREMENT 1.2 (continued)

TABLE 1.2.1 (continued)

ENGINEERED SAFETY FEATURES RESPONSE TIMES INITIATION SIGNAL AND FUNCTION RESPONSE TIME IN SECONDS 4.

Steam Line Pressure--Low a.

Safety Injection (ECCS) 537 (3.5b.10)/27 (4.5b.10) 21 b.

Reactor Trip 52 nu c.

Feedwater Isolation s7 d.

Phase "A" Isolation s 17 (2)/27 (1) e.

Containment Ventilation Isolation N.A.

f.

Motor-Driven Auxiliary Feedwater s 60(I) 21 g.

Station Service Water N.A.

h.

Component Cooling Water N.A.

i.

Essential Ventilation Systems N.A.

j.

Emergency Diesel Generator j

Operation 5 12 k.

Turbine Trip N.A.

1.

Control Room Emergency Recirculation N.A.

m.

Containment Spray Pump N.A.

9 n.

Steam Line Isolation s7 21 COMANCHE PEAK - UNITS 1 AND 2 1-8 Revision 21 January 24. 1996

CPSES/TRM TECHNICAL REQUIREMENT 1.2 (continued)

TABLE '.2.1 (continued)

ENGINEERED SAFETY FEATURES RESPONSE TIMES INITIATION SIGNAL AND FUNCTION RESPONSE TIME IN SECONDS 5.

Containment Pressure--High-3 a.

Containment Spray Pump N.A.

b.

Phase "B" Isolation N.A.

c.

Containment Spray Pump Discharge 9

Valve s 119 6.

Containment Pressure--High-2 Steam Line Isolation s7 21 7.

Steam Line Pressure - Negative Rate-High Steam Line Isolation s7 9

8.

Steam Generator Water Level - High-High a.

Turbine Trip N.A.

b.

Feedwater Isolation 5 11 9.

Steam Generator Water Level - Low-Low a.

Motor-Driven Auxiliary 21 Feedwater 5 60 b.

Turbine-Driven Auxiliary Feedwater s 85

10. Loss-of-Offsite Power Motor-Driven Auxiliary 21 Feedwater Pumps s58(1)

11. Trip of All Main Feedwater Pumps All Auxiliary Feedwater Pumps N.A.

COMANCHE PEAK - UNITS 1 AND 2 1-9 Revision 21 January 24. 1996

CPSES/TRM TECHNICAL REQUIREMENT 1.2 (continued)

TABLE 1.2.1 (continued)

TABLE NOTATIONS (1)

Diesel generator starting and sequence loading delays included.

(2)

Diesel generator starting delay not included. Offsite. power available.

(3)

Diesel generator starting delay included. Only centrifugal charging pumps are included.

(4)

Diesel generator starting delay D01 included. Only centrifugal charging 11 pumps are included.

(Sa)

Sequential transfer of charging pump suction from the VCT.to the RWST (RWST-valves open. then VCT valves close) is not included.

(Sb)

Sequential transfer of charging pump suction from the VCT to the RWST (RWST valves open, then VCT valves close) is included.

(6)

Includes containment pressure relief line isolation only.

(7)

This is a bounding response time for all scenarios.

11 (8)

Response time measured to output of undervoltage channel only.

(9)

Two additional seconds allowable for alternate offsite source breaker trip functions.

(10)

Excludes stroke times of RHR mini-flow valves (FCV-610 and FCV-611).

21 (11)

The response time of s2 seconds is applicable for MODES 1 and 2 and is measured to the loss of stationary gripper coil voltage only. The response time is not applicable (N.A.) for MODES 3 and 4.

BASES 1.2 ENGINEERED SAFETY FEATURES ACTUATION SYSTEM RESPONSE TIMES The bases for the Engineered Safety Features Actuation System are contained in the CPSES Technical Specifications. The measurement of response time at the specified frequencies provides assurance that the Engineered Safety Features 1

actuation associated with each channel is completed within the time limit assumed in the safety analyses. No credit was taken in the analyses for those channels with response times indicated as not applicable. Response time may be demonstrated by any series of sequential, overlapping. or total channel test measurements provided that such tests demonstrate the total channel response time as defined. Sensor response time verification may be demonstrated by either:

(1) in place, onsite, or offsite test measurements, or (2) utilizing replacement sensors with certified response time.

COMANCHE PEAK - UNITS 1 AND 2 1-11 Revision 21 January 24, 1996

CPSES/TRM TECHNICAL REQUIREMENT 2.1 (continued)

TABLE 2.1.1 (continued) i CONTAINMENT ISOLATION VALVES MAXIMUM ISOLATION NOTES AND FSAR TABLE TIME LEAK TEST VALVE NO.

REFERENCE NO.*

LINE OR SERVICE (Seconds) REQUIREMENTS

1. Phase "A" Isolation Valves (continued) 8881 43 SI to RC System 10 N.A.

8 l

Hot Loops #2 &

1. 3 Test Line 2

8824 44 SI to RC System 10 N.A.

8 i

Hot Leg Loops #1 &

1. 4 Test Line 2

8823 45 SI to RC System 10 N.A.

8 Cold Leg Loops #1.

i

1. 2. #3 & #4 Test Line 2

8100 51 Seal Water Return 10 C

8 I

and Excess Letdown 8112 51 Seal Water Return 10 C

8 and Excess Letdown i

7136 52 RCDT Heat Exchanger 10 C

8 to Waste Hold Up Tank LCV-1003 52 RCDT Heat Exchanger 10 C

to Waste Hold Up Tank HV-5365 60 Demineralized Water 10 C

21 Supply HV-5366 60 Demineralized Water 10 C

21 Supply HV-5157 61 Containment Sump 5

C 8

Pump Discharge HV-5158 61 Containment 5

C 8

Sump Pump HV-3487 62 Instrument Air 5

C 8

to Containment COMANCHE PEAK - UNITS 1 AND 2 2-3 Revision 21 January 24, 1996

=

CPSES/TRM TECHNICAL REQUIREMENT 2.1 (continued)

TABLE 2.1.1 (continued)

CONTAINMENT ISOLATION VALVES MAXIMUM ISOLATION NOTES AND FSAR TABLE TIME LEAK TEST VALVE NO.

REFERENCE NO.*

LINE OR SERVICE (Seconds) REQUIREMENTS l

1. Phase "A" Isolation Valves (continued)

HV-4725 114 Containment CCW 10 C

21 Drain Tank Pumps Discharge 1

HV-4726 114 Containment CCW 10 C

21 Drain Tank Pumps Discharge 8027 116 Nitrogen Supply 10 C

8 to PRT 8026 116 Nitrogen Supply 10 C

8 to PRT HV-6084 120 Chilled Water 15 C

21 Supply to Contain-ment Coolers HV-6082 121 Chilled Water 15 C

21 Return From Containment Coolers HV-6083 121 Chilled Water 15 C

21 Return From Containment Coolers HV-4075B 124 Fire Protection 10 C

8 System Isolation HV-4075C 124 Fire Protection 10 C

8 System Isolation

2. Phase "B" Isolation Valves HV-4708 117 CCW Return From 30 C

21 RCP's Motors HV-4701 117 CCW Return From 30 C

21 RCP's Motors HV-4700 118 CCW Supply to 30 C

21 RCP's Motors COMANCHE PEAK - UNITS 1 AND 2 2-7 Revision 21 January 24, 1996

CPSES/TRM a

4 TECHNICAL REQUIREMENT 2 1 (continued)

TABLE 2.1.1 (continued)

CONTAINMENT ISOL ATION VALVES 1

MAXIMUM ISOLATION NOTES AND FSAR TABLE TIME LEAK TEST i

VALVE NO.

REFERENCE NO.*

LINE OR SERVICE (Seconds) REQUIREMENTS

3. Containment Ventilation Isolation Valvt:s (continued)

HV-5548 122 Containment 5

C 21 Pressure Relief Note 8 HV-5549 122 Containment 5

C 21 Pressure Relief Note 8

4. Manual Valves MS-711#

4a TDAFW Pump Bypass N.A.

N.A.

8 Warm up Valve MS-390 Sa N Supply to Steam N.A.

N.A.

8 2

Generator #1 MS-387 9a N, Supply to Steam N.A.

N.A.

8 Generator #2 MS-384 13a N Supply to Steam N.A.

N.A.

8 2

Generator #3 MS-712#

17a TDAFW Pump Bypass N.A.

N.A.

8 Warm-up Valve MS-393 18a N Supply to Steam N.A.

N.A.

8 2

Generator #4 FW-106 20b N, Supply to Steam N.A.

N.A.

8 Generator #1 FW-104 22b N, Supply to Steam N.A.

N.A.

8 Generator #2 FW-102 24b N Supply to Steam N.A.

N.A.

8 2

Generator #3 FW-108 26b N, Supply to Steam N.A.

N.A.

8 Generator #4 7135' 52 RCDT Heat Exchanger N.A.

C 8

to Waste Holdup Tank COMANCHE PEAK - UNITS 1 AND 2 2-9 Revision 21 January 24. 1996

3 TECHNICAL REQUIREMENT 2.1 (continued) o TABLE 2.1.1 (continued)

TABLE NOTATIONS

• Identification code for containment penetration and associated isolation valves in FSAR Tables 6.2.4-1, 6.2.4-2. and 6.2.4-3.

1. May be opened on an intermittent basis under administrative control.

The table does not list local vent, drain and test connections as they are a 14 special class of containment isolation valves and are locked closed to meet containment isolation criteria when located within the penetration boundary.

These valves are subject to the same leak rate testing as the other containment isolation valves in the associated penetration including all applicable leak testing exceptions (see FSAR Table 6.2.4-2 ircluding notes). In addition, if i

these valves are capped (or isolated by blind flange) and under administrative controls they are not required to be leak rate tested.

Note 1:

All four MSIV bypass valves are locked closed in Mode 1. During Mode 2.

3. and 4 one MSIV bypass valve may be opened provided the other three MSIV bypass valves are locked closed and their associated MSIVs are closed.

Note 2:

These valves require steam to be tested and are thus not required to be tested until the plant is in MODE 3.

Note 3:

These valves are included for table completeness: the requirements of Specification 3.6.3 do not apply.

Instead, the requirements of 3

Specification 3.7.1.1. 3.7.1.5. 3.7.1.6 and 3.7.1.7 apply for main steam safety valves, main steam isolation valves, feedwater isolation valves and steam generator atmospheric relief valves, respectively.

Note 4:

These valves are leak tested in accordance with Technical Specification 2

Surveillance Requirement 4.6.1.2.

Note 5:

10 CFR 50 Appendix J. Type C testing of these valves is satisfied by the testing of the airlock under Technical Specification Surveillance 6

Requirement 4.6.1.3b.

Note 6:

These valves are considered an integral part of the airlock associated with their respective airlock door. Therefore, they are subject to the 6

controls of Specification 3.6.1.3.

Note 7:

These valves are secured in position by hydraulic system locks and/or interlocks and do not require separate locks.

6 Note 8:

Including the instrumentation delays of the containment ventilation 21 isolation signal from Pressurizer Pressure Low.

l l

l COMANCHE PEAK - UNITS 1 AND 2 2-25 Revision 21 January 24. 1996

6 COMANCHE PEAK STEAM ELECTRIC STATION UNITS 1 & 2 TECHNICAL REQUIREMENTS MANUAL (TRM)

EFFECTIVE PAGE LISTING BELOW IS A LEGEND FOR THE EFFECTIVE PAGE LISTING:

Original Submitted July 21. 1989 Revision 1 September 15, 1989 Revision 2 January 15. 1990 Revision 3 July 20, 1990 Revision 4 April 24, 1991 Revision 5 September 6. 1991 Revision 6 November 22, 1991 Revision 7 March 18,1992 Revision 8 June 30, 1992 Revision 9 Pa.%ter 18,1992 Revision 10 January 22, 1993 Revision 11 February 3, 1993 Revision 12 July 15, 1993 Revision 13 September 14. 1993 Revision 14 November 30, 1993 Revision 15 April 15.1994 Revision 16 May 11, 1994 Revision 17 February 24. 1995 Revision 18 April 14, 1995 Revision 19 May 15. 1995 Revision 20 June 30, 1995 Revision 21 January 24, 1996 EPL-1 January 24, 1996

o s

COMANCHE PEAK STEAM ELECTRIC STATION UNITS 1 & 2 TECHNICAL RE0'JIREMENTS MANUAL (TRM)

EFFECTIVE PAGE LISTING TRM Tab Original Record of Changes February 24. 1995 TRM-Title Page June 30. 1992 Table of Contents-Tab Original i

February 24, 1995 Administrative Controis-Tab Original Administrative Controls-Title Page June 30, 1995 0-1 Revision 20 0-2.

Revision 20 0-3 Revision 20 0-4 Revision 20 Technical Requirements-Tab Original Section 1-Tab Original 1-1 Revision 20 1-2 Revision 21 1-3 Revision 21 1-4 Revision 20 1-5 June 30. 1995 1-6 Revision 21 1-7 Revision 21 1-8 Revision 21 1-9 Revision 21 1-10 June 30. 1995 1-11 Revision 21 1-12 June 30. 1995 1-13 June 30. 1995 1-14 June 30, 1995 1-15 June 30. 1995 1-16 June 30, 1995 1-17 June 30, 1995 1-18 June 30, 1995 1-19 June 30, 1995 Sec. 2-Tab Original i

2-1 Revision 20 2-2 June 30, 1995 2-3 Revision 21 2-4 June 30. 1995 2-5 June 30. 1995 2 June 30. 1995 2-7 Revision 21 2-8 June 30, 1995 2-9 Revision 21 EPL 2 January 24, 1996 r

43 9

COMANCHE PEAK STEAM ELECTRIC STATION UNITS 1 & 2

-l TECHNICAL REQUIREMENTS MANUAL (TRM) i EFFECTIVE PAGE LISTING 2-10 June 30, 1995 l

2-11 June 30, 1995 4

2-12' June 30, 1995 2-13 June 30, 1995 l

2-14.

June 30, 1995 2-15 June 30, 1995 t

2-16 June 30, 1995 2-17 June 30, 1995 l

2-18 June 30, 1995 2-19 June 30, 1995 2-20.

June 30, 1995 2-21 June 30, 1995 2-22 June 30, 1995 2-23 June 30, 1995 j

2-24 June 30, 1995 2-25 Revision 21 2-26 June 30, 1995 l

2-27 Revision 20 2-28 June 30, 1995 Sec. 3-Tab Original

~3-1 Revision 20 l

3-2 June 30, 1995 3-3 June 30, 1995 34 June 30, 1995 3-5 June 30, 1995 3-6 June 30, 1995 3 June 30, 1995 3-8 June 30, 1995 3-9 June 30, 1995 3-10 June 30, 1995 Sec. 4-Tab Original 4-1 Revision 20 4-2 June 30, 1995 4-3 June 30, 1995 4-4 June 30, 1995 45 June 30, 1995 4-6 June 30, 1995 4-7 June 30, 1995 48 June 30, 1995 4-9 June 30, 1995 4-10 June 30, 1995 4 11 June 30, 1995 EPL-3 January 24, 1996 i=,

~ _

. - ~ = _...

_~ -...--.

o-f l

COMANCHE PEAK STEAM ELECTRIC STATION UNITS 1 & 2 TECHNICAL REQUIREMENTS MANUAL (TRM) t EFFECTIVE PAGE LISTING 4-12 June 30, 1995 l

4-13 June 30, 1995 4 14 June 30. 1995 4-15 June 30, 1995-

'4-16 June 30, 1995 4-17 June 30, 1995 l

4-18 June 30, 1995 4-19 June 30, 1995 4-20 June 30, 1995 l

l 4-21 June 30, 1995 4-22 June 30, 1995 i

4 23 June 30,1995 4-24 June 30, 1995 4 25 June 30, 1995 4-26 June 30,1995 4-27 June 30, 1995 4-28 June 30. 1995 l

4-29 June 30. 1995 EPL-Tab

. Original EPL-1 January 24, 1996 EPL-3 January 24, 1996 EPL-2 January 24, 1996 I

EPL-4 January 24, 1996 l-1 l

1 l

l EPL-4 January 24. 1996 I

l

.