Text

Amend 105 to License NPF-29,modifying Selected TS Instrumentation Surveillance Test Intervals & Allowed Outage Times Based on GE Repts GENE-770-06-1 & GENE-770-06-2
	ML20127B814
Person / Time
Site:	Grand Gulf
Issue date:	01/06/1993
From:	Larkins J; Office of Nuclear Reactor Regulation
To:	;
Shared Package
ML20127B818	List: ML20127B814; ML20127B819;
References
	NUDOCS 9301130139
	Download: ML20127B814 (39)
	v • d • e

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'o, UNITED STATES 85 NUCLEAR REGULATORY COMMISSION h g

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[NTERGY OPERATIONS. INC.

SYSTEM ENERGY RESOURCES. INC.

ELVTH MISSIS $1PPI ELECTRIC POWER ASSOCIATION MISSISSIPPI POWER AND LIGHT COMPANY DOCKET NO. 50-416 GRAND _WLF NUCLEAR STATION, UNIT 1 AMENDMENT 10 FAClllTY OPERATING LICENSE Amendment No.105 License No. NPf-29 1.

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

A.

The application for amendment by Entergy Operations, Inc. (the licensee) dated July 29, 1992, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's rules and regulations set forth in 10 CFR Chapter I; 8.

The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; C.

There is reasonable assurance (i) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (11) that such. activities will be conducted in compliance with the Commission's regulations; D.

The issuance of this emendment will not be inimical to the common defense and security or to the health and safety of the public; and E.

The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied.

9301130139 930103 PDR ADOCK 05000416-

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' 2.

Accordingly, the license is amended by changes to the Technical Specifications, as indicated in the attachment to this license amendment; and paragraph 2.C.(2) of Facility Operating License No. NPF-29 is hereby amended to read as follows:

(2)

Igchnical Specifications The Technical Specifications contained in Appendix A and the Environmental Protection Plan contained in Appendix B, as revised through Amendment No.105, are hereby incorporated into this license.

Entergv Operations, Inc. shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.

3.

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

FOR THE NUCLEAR REGULATORY: COMMISSION N

=- W k John T. Larkins, Director Project Directorate IV-1 Division of Reactor Projects - III/IV/V-Office of Nuclear Reactor Regulation

Attachment:

Changes to the Technical Specifications Date of Issuance: January 6, 1993

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i A1T ACHMENT T0 LICENSE AMENDMENT NO 105 FAClllTY OPERATING LICENSE NO, NPF-29 DOCKET No. 50-416 Replace the following pages of the Appendix A Technical Specifications with the attached pages.

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.

B[ MOVE PAGES IMSfRT PAGES 3/4 3-41 3/4 3-41 3/4 3-43 3/4 3-43 3/4 3-46 3/4 3-46 3/4 3-48 3/4 3-48 3/4 3-49 3/4 3-49 3/4 3-51 3/4 3-51 3/4 3-52 3/4 3-52 3/4 3-53 3/4 3-53 3/4 3-54 3/4 3-54 3/4 3-60 3/4 3-60 3/4 3-61 3/4 3-61 3/4 3-62 3/4 3-62 3/4 3-93 3/4 3-93 3/4 3-94 3/4 3-94 3/4 3-96 3/4 3-96 3/4 4-5 3/4 4-5 3/4 4-6 3/4 4-6 3/4 4-7 3/4 4-7 3/4 5-9 3/4 5-9 3/4 5-10 B 3/4 3-3a B 3/4 3-3a B 3/4 3-3b B 3/4 3-4 B 3/4 3-4 B 3/4 3-6 B 3/4 3-6 B 3/4 4-2 B 3/4 4-2 B 3/4 4-2a B 3/4 5-3 B 3/4 5-3

INSTRUMENTATION END-OF-CYCLE RECIRCULATION PUMP TRIP SYSTEM INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.4.2 The end-of-cycle recirculation pump trip (EOC-RPT) system instrumentation channels shown in Table 3.3.4.2-1 shall be OPERABLE with their trip setpoints set consistent with the values shown in the Trip Setpoint column of Table 3.3.4.2-2 and with the END-OF-CYCLE RECIRCULATION PUMP TRIP SYSTEM RESPONSE TIME as shown in Table 3.3.4.2-3.

APPLICABillTY:

OPERATIONAL CONDITION 1, when THEPJiAL POWER is greater than or equal to 40% of RATED THEPJ4AL POWER.

ACTION:

a.

With an end-of-cycle recirculation pump trip system instrumentation channel trip setpoint less conservative than the value shown in the Allowable Values column of Table 3.3.4.2-2, declare the channel inoperable until the channel is restored to OPERABLE status with the channel setpoint adjusted consistent with the Trip Setpoint value.

b.

With the number of OPERABLE channels one less than required by the Minimum OPERABLE Channels per Trip System requirement for one or both trip systems, place the inoperable channel (s) in the tripped condition within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

I c.

With the number of OPERABLE channels two or more less than required by the Minimum OPERABLE Channels per Trip System requirement for one trip system and:

1.

If the inoperable channels consist of one turbine control valve channel and one turbine stop valve channel, place both inoperable channels in the tripped condition within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

]

2.

If the inoperable channels include two turbine control valve channels or two turbine stop valve channels, declare the trip system inoperable.

d.

With one trip system inoperable, restore the inoperable trip system to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or reduce THERMAL POWER to less than 40% of RATED THERMAL POWER within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

e.

With both trip systems inoperable, restore at least one trip system to OPERABLE status within one hour or reduce THERMAL POWER to less than 40% of RATED THERMAL POWER within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

GRAND GULF-UNIT 1 3/4 3-41 Amendment No. 105

l INSTRUMENTATION SURVEILLANCE REQUIREMENTS 3

4.3.4.2.1 Each and-of-cycle recirculation pump trip system instrumentation channel shall be demonstrated OPERABLE by the performance of the CHANNEL FUNCTIONAL TEST and' CHANNEL CALIBRATION operations at the frequencies shown.

in Table 4.3.4.2.1-1.

4.3.4.2.2.

LOGIC SYSTEM FUNCTIONAL TESTS and simulated automatic operation of all channels shall be performed at least once per 18 months.

4.3.4.2.3 The END-0F-CYCLE RECIRCULATION PUMP TRIP SYSTEM RESPONSE TIME of each trip function shown in Table-3.3.4.2-3 shall be demonstrated to be within its limit-at least once per 18 months. - Each test shall include two turbine control valve channels from one trip system and two. turbine stop valve channels from the other trip system such that all channels.are-tested at _least -

once per 36 months. The-time required for Breaker Interruption" shall be verified at least once per 60 months and added to the 18-month trip system times to verify that the overall END-OF-CYCLE RECIRCULATION PUMP TRIP RESPONSE TIME is within its limit.

11

" Breaker-Interruption time is defined as Breaker' Response time plus Arc.

Suppression time. Breaker Response is the time'from application of voltage to-the trip coil until the main contacts separate. Arc-Suppression is the time from main contact separation until the complete suppression of the electrical arc across the open contacts. - Breaker Response shall be verified by testing and added to the manufacturer's design Arc Suppression time-of'12 as to detsr-aine Breaker Interruption time. The breaker are: suppression time shall-be validated by the performance of periodic contact gap measurements and high potential tests on the breaker vacuum interrupters in accordance with plant-

_ procedures.

GRAND GULF-UNIT 1 3/4 3-42 Amendment No.18 [

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TABLE 3.3.4.2-1 DlD-OF-CYCLE RECIRCULATION PUMP TRIP SYSTEM INSTRUMENTATION HINIMUM OPERABLE CHANNELS PER TRIP FURCTION TRIP SYSTEM (')

1.

Turbine Stop Valve - Closure 2(b) 2.

Turbine Control Valve - Fast Closure 2(b)

A trip system may be placed in an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for

(

(')

required surveillance provided that the other trip system is OPERABLE.

(b)

This function shall be automatically bypassed when operating below the appropriate turbine first stage pressure setpoint of (1) s 26.9% of the value of turbine first-stage pressure at valves wide open (VWO) steam flow when operating with rated feedwater temperature of greater than or equal to 420*F; or (2) s 22.5% of the value of turbine first-stage pressare at VWO steam flow when operating with rated feedwater temperature between 370*F and 420*F.

These represent allowable setpoint values of turbine first-stage pressure equivalent to THERMAL POWER less than 40% of RATED THERMAL POWER.

GRAND GULF-UNIT 1 3/4 3-43 Amendment No. 44,105

- _ _ =

9 TABLE 3.3.4.2-2 END-OF-CYCLE RECIRCULATION PUMP TRIP SYSTEM SETPOINTS TRIP ALLOWABLE TRIP FUNCTION SETPOINT VALUE 1.

Turbine Stop Valve - Closure 1 40 psig*

1 37 psig 2.

Turbine Control Valve - Fast

~

Closure 1 44.3 psig*

1 42 psig

Initial setpoint.

Final setpoint to be determined during startup test program.

Any required change to this setpoint shall be submitted to the Commission withir 90 days of test completion.

GRAND GULF-UNIT 1 3/4 3-44

t INSTRUMENTATION 1ABLE 3.3.4.2-3 END-OF-CYCLE RECIRCULATION PUMP TRIP SYSTEM RESPONSE TIME TRIP Fl!NCTION RESPONSE TIME (Milliseconds) 1.

Turbine Stop Valve - Closure 5 190 2.

Turbine Control Valve - Fast Closure

< 190 l

l l

GRAND GULF-UNIT 1 3/4 3-45

TABLE 4.3.4.2.1-1 END-OF-CYCLE RECIRCVLATION PUMP TRIP SYSTEM SURVEILLANCE REQUIREMENTS CHANNEL FUNCT10NAL CHANNEL TRIP FUNCTIDH TEST CALIBRATION 1.

Turbine Stop Valve - Closure Q*

R' 2.

Turbine Control Valve - Fast Closure Q*

R'

Including Trip system logic testing.

alibrate trip units and logic at least once per 92 days.

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GRAND GULF-UNIT 1 3/4 3-46 Amendment No. 44,105 i

INSTRUMENTATION 3/4.3.5 REACTOR CORE ISOLATION COOLING SYSTEM ACTUATION INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.5 The reactor core isolation cooling (RCIC) system actuation instrumenta-tion channels shown in Table 3.3.5-1 shall be OPERABLE with their trip set-points set consistent with the values shown in the Trip Setpoint column of Table 3.3.5-2.

APPLICABILITY: OPERATIONAL CONDITIONS 1, 2 and 3 with reactor steam dome pressure greater than 135 psig.

ACTION:

a.

Wito a RCIC system actuation instrumentation channel trip setpoint less conservative than the value shown in the Allowable Values column of Table 3.3.5-2, declare the channel inoperable unti) the channel is restored to OPERABLE status with its trip setpoint adjusted consistent with the Trip Setpoint value.

b.

With one or more RCIC system actuation instrumentation channels inoperable, take the ACTION required by Table 3.3.5-1.

SURVEILLANCE REQUIREMENTS 4.3.5.1 Each RCIC system actuation instrumentation channel shall be demon-strated OPERABLE by the performance of the CHANNEL CHECK, CHANNEL FUNCTIONAL TEST and CHANNEL CALIBRATION operations at the frequencies shown in Table 4.3.5.1-1.

4.3.5.2 1.0GIC SYSTEM FUNCTIONAL TESTS and simulated automatic operation of all chonnels shall be performed at least once per 18 months.

GRAND GULF-UNIT I 3/4 3-47 r

c' TABLE 3.3.5-1 95 REACTOR CORE ISOLATION COOLING SYSTEM ACTUATION INSTRUMENTATION E

HINIMUM G

OPERABLE CilANNELS(-

ACTION FUNCTIONAL UNITS 5

a.

Reactor Vessel Water Level - Low Low, level 2 4

50 b.

Reactor Vessel Water Level - liigh, Level 8 2

51 i -

c.

Condensate Storage Tank Water Level - Low 2

52 d.

Suppression Pool Water Level - liigh 2

52 e.

'Hanual Initiation 1

53 A channel may be placed in en inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for required surveillance without l

(*)

placing the trip system in the tripped condition provided at least one other OPERABLE channel in the y-g samel trip system is monitoring that parameter.

N a

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4 TABLE 3.3.5-1 (Continued)

REACTOR CORE ISOLATION COOLING SYSTEM ACTUATION INSTRUMENTATION ACTION 50 -

With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels requirement:

a.

With one channel inoperable, place the inoperable channel in the tripped condition within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or declare the RCIC system inoperable.

b.

With more than one channel inoperable, declare the RCIC system inoperable.

ACTION 51 -

With the number of OPERABLE channels less than required by the minimum OPERABLE ci,annels requirement, declare the RCIC system inoperable within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

I ACTION 52 -

With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels requirement, place at least one inoperable channel in the tripped condition within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or I

declare the RCIC system inoperable.

ACTION 53 -

With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels requirement, restore the inoperable channel to OPERABLE status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or declare the RCIC l

system inoperable.

~

GRAND GULF-UNIT 1 3/4 3-49 Amendment No. 105l

E TABLE 3.3.5-2 f$

REACTOR CORE ISOLATION COOLING SYSTEM ACTUATION INSTRUMENTATION SETPOINTS c:

ALLOWABLE

((

FUNCTIONAL UNITS TRIP SETPOINT VALUE a.

Reactor Vessel Water Level -

Low Low, level 2 1 -41.6 inches

1 -43.8 inches b.

Reactor Vessel Water Level - High, Level 8 5 53.5 inches *

$ 55.7 inches c.

Condensate Storage Tank Level - Low 2 0 inches

> -3 inches d.

Suppression Pool Water Level - liigh 5 5.9 inches 5 7.0 inches g;

e.

Manual Initiation NA NA s

T El

See Bases Figure B 3/4 3-1.

m 4

e

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o TABLE 4.3.5.1-1 e

g REACTOR CORE ISOLATION COOLING SYSTEM ACTUATION INSTRUMENTATION SURVEILLANCE REQUIREMENTS T

CHANNEL E5 CHANNEL FUNCTIONAL CHANNEL El FUNCTIONAL UNITS CHECK TEST CALIBRATION a.

Reactor Vessel Water Level -

Low low, level 2 S

Q R

b.

Reactor Vessel Water S

Q R

Level - High, level 8 c.

Condensate Storage Tank Level - Low S

Q R

d.

Suppression Pool Water level -

2d High S

Q R

a e.

Manual Initiation NA Q*)

NA

(*) Calibrate trip unit at least once per 92 days.

I

) Manual ' initiation switches shall be tested at least once per 18 months during shutdown. All other circuitry associated with manual initiation shall receive a CHANNEL FUNCTIONAL TEST at least once per 92 days as a part of circuitry required to be tested for automatic system actuation.

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a a

E.F W

INSTRUMENTATION 3 /4. 3,6 CONTROL ROD BLOCK INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.6.

The control rod block instrumentation channels shown in Table 3.3.6-1 shall be OPERABLE with their trip setpoints set consistent with the values shown in the Trip Setpoint column of Table 3.3.6-2.

APPLICABILITY: As shown in Table 3.3.6-1.

~~

&(TlQH:

a.

With a control rod block instrumentation channel trip setpoint less conservative than the value shown in the Allowable Values column of Table 3.3.6-2, declare the channel-inoperable until the channel is

~

restored to OPERABLE status with its trip setpoint adjusted consistent with the Trip Setpoint value.

b.

With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip Function requirement, take the ACTION required by Table 3.3.5-1.

SURVEILLANCE REOUTREMENTS 4.3.6.1 Each of the above required control rod block trip systems and instrumentation channels shall be demonstrated OPERABLE

by the performance of l

the CHANNEL CHECK, CHANNEL FUNCTIONAL TEST and CHANNEL CALIBRATION operations for the OPERATIONAL CONDITIONS and at the frequencies shown in Table 4.3.6-1.

4.3.6.2 The provisions of Specification 4.0.4 are not applicable to the Channel Functional test surveillances fcr the Intermediate Range Monitors and Source Range Monitors for entry into their applicable OPERATIONAL CONDITIONS (as specified in Table 4.3.6-1) from OPERATIONAL CONDITION 1, provided the surveillances are performed within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after such entry.

A channel may be placed in an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for required surveillance without placing the trip system in the tripped condition, provided at least one other OPERABLE channel in the same trip system is monitoring that parameter.

GRAND GULF-UNIT 1 3/4 3-52 Amendment No. M1,105

TABLE 3.3.6-1 CONTROL RCD BLOCK INSTRUMENTATION MINIMUM APPLICABLE y

OPERABLE CilANNELS OPERATIONAL z

TRIP FUNCTION PER TRIP FUNCTION CONDITIONS ACTION CG 1.

R00 PATTERN CONTROL SYSTEM E-a.

Low Power Setpoint 2

1, 2 60

b. High Power Setpoint 2

I#

60 2.

APRM

~

a.

Flow Blased Neutron Flux-Upscale 6

1 61 b.

Inoperative 6

1, 2, 5 61 c.

Downscale 6

1 61 d.

Neutron Flux - Upscale, Startup 6

2, 5 61

-l SOURCE RANGE MONITORS 3.

Detector not full in(a) 4 2##

61 a.

2**

5 62 ID) 4 2##

61 b.

Upscale 2**

5 62 s

Inoperative (b) 4 2##

61:

c.

2**

5 62 l

d.

Downscale(c) 4 2##

61 2**

5 62 4.

INTERMEDIATE RANGE MONITORS a.

Detector not full in 6

2, 5 61 b.

Upscale 6

2, 5 61 6

2, 5 61 p,

Inoperatig) g c.

6 2, 5 61 Downscale R

d.

%a 5.

SCRAM DISCHARGE VOLUME a.

Water Level-High 2

1, 2, 5*

64 l

2

?

6.

REACTOR COOLANT SYSTEM RECIRCULATION FLOW a.

Upscale 3

1 64 l

l S

7.

REACTOR MODE SWITCH SHUTDOWN POSITION 2

3, 4 63

'w

-1NSTRUMENTATION TABLE 3.3.6_1 (Continued)

CONTROL R0D BLOCK INSTRUMENTATION ACTION ACTION 60 Declare the RPCS inoperable and take the ACTION required by Specification 3.1.4.2.

ACTION 61 With the number of OPERABLE Chantiels:

a.

One less than required by the Minimum OPERABLE Channels per Trip Function requirement, restore the inoperable channel to OPERABLE status within 7 days or place the inoperable channel in the tripped condition within the next hour.

b.

Two or more less than required by the Minimum OPERABLE Channels per Trip Function requirement, place at least one inoperable channel in the tripped condition within one hour.

ACTION 62 -

With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip Function requirement, place the inoperable channel in the tripped condition within one hour.

ACTION 63 With the number of OPERABLE channels less than required by_

the Minimum OPERABLE Channels per Trip Function requirement, initiate a rod block.

ACTION 64 -

With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip Function requirement, place the inoperable channel in the tripped condition within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

NOTES With more than one control rod withdrawn.

Not applicable to control rods removed 'per Specification 3.9.10.1 or 3.9.10.2.

OPERABLE channels must be associated with SRMs required OPERABLE per Specification 3.9.2.

With THERMAL POWER greater than the Low Power Setpoint.

Whenever the related function is not bypassed as specified in notes (a) through (c).

(a) This function shall be automatically bypassed if detector count rate is >

100 cps or the IRM channels are on range 3 or higher.

(b) This function shall be automatically bypassed when the associated IPJi channels are on range 8 or higher.

(c) This function shall be automatically bypassed when the IRM channels are on range 3 or higher.

(d) This function shall be automatically bypassed when the IRM channels are on range 1.

GRAND GULF-UNIT 1 3/4 3-54 Amendment No. 69, M1,105

TABLE 3.3.7.1-1 (Continued) g RADIATION MONITORING INSTRUMENTATION 5

E MINIMUM CilANNELS APPLICABLE ALARM / TRIP MEASUREMENT c3 7'

INSTRUMENTATION OPERABLE CONDITIONS SETPOINT RANGE ACTION

10. Area Monitors a.

Fuel Handling Area Monitors 3

1)

New Fuel 1

(e) 52.5 mR/hr/NA 10_2 to 10 mR/hr 72 3

2)

Spent Fuel 1

(f) 52.5 mR/hr/NA 10-2 Storage Vault to 10 mR/hr 72 i

l Storage Pool 3

3)

Dryer Storage 1 (g) 52.5 mR/hr/NA 10 2 to 10 mR/hr 72 Area 3

b.

Control Room 1

At all times 50.5 mR/hr/NA 10 2 to 10 mR/hr 72 Radiation Monitor E

With RHR heat exchangers in operation.

[

When irradiated fuel is being handled in the primary or secondary containment.

Initial setpoint. Final Setpoint to be determined during startup test program. Any required change to 4

o f

this setpoint shall be submitted to Commission within 90 days after test completion.

With ADilR heat exchangers in operation.

f Trips system with 2 channels upscale-Hi Hi Hi, or one channel upscale ill Hi Hi and one channel downscale or (a) 2 channels downscale.

(b)

Isolates containment /drywell purge penetrations.

With irradiated fuel in spent fuel storage pool.

(c)

(d) Also isolates the Auxiliary Building and Fuel Handling Area Ventilation Systems.

(e) With fuel in the new fuel storage vault.

(f) With fuel in the spent fuel storage pool.

With fuel in the dryer storage area.

(g)

Two upscale Hi Hi, one upscale Hi Hi and one downscale, or two downscale signals from the same trip F

(h)

A channel may be system actuate the trip system and initiate isolation of the associated isolation valves.

placed in an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for required surveillance without placing the trip system in the tripped condition, provided at least one other OPERABLE channel in the same trip system is monitoring 8

that parameter.

5 L

I I

I TABLE'3.3.7.1-1 (Continued) i RADIATION MONITORING INSTRUMENTATION ACTION ACTION 70 With the required monitor inoperable, obtain and analyze at least one grab sample of the monitored parameter at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

ACTION 71

[ DELETED)

ACTION 72-With the required monitor inoperable, perform area surveys of the monitored area with portable monitoring instrumentation at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

ACTION 73 -

a.

With one of the required monitors in a trip system inoperable, place the inoperable channel in the downscale tripped condition within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; restore.the inoperable l

channel to OPERABLE status within 7 days, or, within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , initiate and maintain operation of at least one control room emergency filtration system in the isolation mode of operation.

b.

With both of the required monitors in a trip system inoperable, initiate and maintain operation of at least one control room emergency filtration system in the isolation mode of operation within one hour.

ACTION 74 With one of the required monitors in a trip system a.

inoperable, place the inoperable channel in the downscale tripped condition within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

1 b.

With two of the required monitors in a trip system inoperable, isolate the containment and drywell purge and vent penetrations within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

ACTION 75 -

a.

With one of the required monitors in a trip system inoperable, place the inoperable channel in the downscale tripped condition within-24 hours.

I b.

With two of the required monitors in a trip system inoperable, establish SECONDARY CONTAINMENT INTEGRITY with at least one standby gas treatment subsystem operating within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

1 GRAND GULF-UNIT 1 3/4 3-61 Amendment No. 105

TABLE 4.3.7.1-1 RADIATION MONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTS OPERATIONAL n

CHANNEL CONDITIONS FOR gg CHANNEL FUNCTIONAL CHANNEL WHICH SURVEILLANCE g

INSTRUMENTATION CHECK TEST CALIBRATION REQUIRED h

1.

Component Cooling Water Radiation 7'

Monitor S

M A

At all times E

2.

Standby Service Water System p

Radiation Monitor S

M A

1, 2, 3, and*

3.

P1 ant Scrvice Water System Radiation Monitor S

M A

i 4.

[ DELETED]

5.

Carbon Bed Vault Radiation Monitor S

M A

1, 2 6.

Control Room Ventilation Radiation Monitor S

Q(*'

A 1, 2, 3, 5 and**

7.

Containment and Drywell Ventilation Exhaust Radiation Monitor S

Q A

At all times 8.

Fuel Handling Area Ventilation Radiation Monitor S

Q A

1, 2, 3, 5 and**

9.

Fuel Handling Area Pool Sweep w

Exhaust Radiation Monitor S

Q A

(b) 1

10. Area Monitors w

a.

Fuel Handling Area Monitors in 1)

New fuel Storage Vault S

M R

(c) 2)

Spent Fuel Storage Pool S

M R

(d) 3)

Dryer Storage Area S

M R

(e) b.

Control Room Radiation Monitor S

M R

At all times With RHR heat exchangers'in operation.

When irradiated fuel is being handled in the primary or secondary containment.

(a) The CHANNEL FUNCTIONAL TEST shall demonstrate that control room annunciation occurs if any of the following conditions exist.

1.. Instrument indicates measured levels above the alarm / trip setpoint.

2.

Circuit failure, p

3.

Instrument indicates a downscale failure.

g 4.

Instrument controls not in Operate mode.

g-(b) With irradiated fuel in the spent fuel storage pool, g

(c) With fuel in the new fuel storage vault.

(d) With fuel in the spent fuel storage pool.

o g

(e) With fuel in the dryer storage area.

With ADHR heat exchangers in operation.

L

8 0

e N

bump

TABLE 3.3.8-1 PLANT SYSTEMS ACTUATION INSTRUMENTATION o

MINIMUM APPLICABLE OPERABLE CilANNELS OPERAIIONAL Ei TRIP FUNCTION PER TRIP SYSTEM

CONDITIONS ACTION E

g; 1.

CONTAINMENT SPRAY SfSiiH h

a.

Drywell Pressure-flign 2

1, 2, 3 130 b.

Containment Pressure-High 1

1, 2, 3 131 c.

Reactor Vessel Water level-Low Low Low, level 1 2

1, 2, 3 130 d.

Timers

1) System A 1

1,2,3 131

2) System B 1

1, 2, 3 131 2.

FEEDWATER SYSTEM / MAIN TURBINE TRIP SYSTEM a.

Reactor Vessel Water Level-liigh, level 8 3

1 132 3.

SUPPRESSION POOL MAKEUP SYSTEM a.

Drywell Pressure - High (ECCS) 2 1,2,3 135 b.

Drywell Pressure - High (RPS) 2 1,2,3 135 c.

Reactor Vessel Water Level - Low Low Low, Level 1 2

1, 2, 3 135 d.

Reactor Vessel Water Level - Low Low, Level 2 2

1,2,3 135 e.

Suppression Pool Water Level - Low Low 1

1, 2, 3 133 f.

Suppression P901 Makeup Timer-1 1, 2, 3 133 g.

SPMll Manual Initiation 2

1,2,3 134 k

(*)

A channel may be placed in an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months (2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for Reactor Vessel Water Level - liigh, level 8 instrumentation) during periods of required. surveillance provided at least one other OPERABLE channel in the same trip L

system is monitoring that. parameter.

Pn l

.l Mb L t. J.0.0 1 Wullb illucu) e PLANT SYSTEMS ACTUATION INSTRUMENTAT10" ACTION ACTION 130 -

a.

With the number of OPERABLE channels cae less than required by the Minimum OPERABLE Channels per Trip System requirement, place the inoperable channel in the tripped condition within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ; otherwise, declare the asso-l-

ciated containment spray system inoperable and take the action required by Technical Specification 3.6.3.2.

b.

With the number of OPERABLE channels two less than required by the Minimum OPERABLE channels per Trip System requirement, declare the associated containment spray system inoperable and take the action required by Technical Specification 3.6.3.2.

ACTION 131 -

With the number of OPERABLE channels-less than required by the Minimum OPERABLE Channels per Trip System requirement, restore the inoperable channels to OPERABLE status within one hour; otherwise, declare the associated containment spray system inoperable and take the action required by Technical Specification 3.6.3.2.

ACTION 132 -

for the feedwater system / main turbine trip system:

a.

With the number of OPERABLE channels one less than required by the Minimum OPERABLE Channels requirement, restore the inoperable channel to OPERABLE status within 7 days or be in at least STARTUP within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , b.

With the number of OPERABLE channels two less than.

required by the Minimum OPERABLE Channels per Trip System requirement, restore at least one of the inoperable channels 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 STARTUP within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

ACTION 133 -

With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip System requirement, declare -

the associated suppression pool makeup system inoperable and take the action required by Specification 3.6.3.4.

ACTION 134 -

With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip System requirement, restore the inoperable channels to OPERABLE status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ; I

otherwise, declare the associated suppression pool makeup system inoperable and take the action required by Specification 3.6.3.4.

ACTION 135 -

With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip Function requirement:

a.

With one channel inoperable, place the inoperable channel in the tripped condition within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or declare the l

associated system (s) inoperable, b.

With more than one channel inoperable, declare the associated system (s) inoperable.

GRAND GULF-UNIT 1 3/4 3-94 Amendment No. 69, 87,105

-l mg 1 ALE 3.3.8-2 o

PLANT SYSTEMS ACTUAT10M INSTRIMENTATION SETPOINTS n

l5 -

n

,g TRIP FUNCTION ALLOWABLE TRIP SEIPOINT VALUE l

~

[

1.

CONTAINMENT SPRAY SYSTEM t

a.

Drywell Pressure-High

< 1.39 psig

< 1.44 psig b.

Containment Pressure-High i 7.84 psig

-I S.34 psig i

c.

Reactor Yessel Water Level-tow Low Low, Level 1

> - 150.3 inches 1 - 152.5 inches d.

Timers

1) System A 10.85 + 0.10 minutes 10.26 - 0.00, + 1.18 minutes

2) System 8 10.8510.10 minutes **

10.26 - 0.00, + 1.18 minutes i

2.

FEEDWATER SYSTEM / MAIN TURBINE TRIP SYSTEM wD a.

Reactor Yessel Wa' r Level-High, tevel 8 1 53.5 inches *

$ 54.1 inches w

3.

SUPPRESSION M 0L MAKEUP SYSTEM a.

Drywell Pressure - High (ECCS) i 1.39 psig i 1.44 psig k

Drywell Pressure - High (RPS) i 1.23 psig i 1.43 psig o

c.

Reactor Vessel Water Level - Low t

low Low, Level 1 1 -150.3 inches

1-152.5 inches d.

Reactor Vessel Water Level - Low i

Low, Level 2 1 -41.6 Inches

1 -43.8 inches y

e.

Suppression Pool Water Level - Low Low 1 17 ft 5 inches 117ft2 inches i

[

f.

Suppression Pool Makeup Timer i 29.0 minutes 1 29.5 minutes t

)g g.

SPMU Manual. Initiation MA NA l

'o 2"-

@.i

- - See Bases Figure B 3/4 3-1.

Setpoint for System B is the sum of E12-K0938 plus E12-K116.

E12-K116 is not to exceed 10.00 seconds.

=

J;"

[

m-

TABLE 4.3.8.I-1 PLANT SYSTEMS ACTUATION INSTRUMENTATION SURVEILLANCE REQUIREMENTS c,

k CHANNEL OPERATIONAL 6

CilANNEL FUNCTIONAL CilANNEL CONDITIONS IN WHICH gt TRIP FUNCTION CllECK TEST CALIBRATION SURVEILLANCE REQUIRED l.

CONTAINHENT SPRAY SYSTEM z

U a.

Drywell Pressure-High S

Q R(

I, 2, 3 b.

Containment Pressure-High S

Q R

1, 2, 3 c.

Reactor Vessel Water Level -

R(

1, 2, 3 l

Low Low Low, Level 1 5

Q d.

Timers NA Q

Q 1, 2, 3 2.

FEEDWATER SYSTEH/ MAIN TURBINE TRIP SYSTEM Reactor Vessel Water Level-High, S

M R

1 a.

Level 8 3.

SUPPR'ESSION POOL MAKEUP SYSTEM a.

Drywell Pressure - High (ECCS)

S Q

R(

1, 2, 3 b.

Drywell Pressure - High (RPS)

S Q

R(

1, 2, 3 c.

Reactor Vessel Water Level - Low R(

1, 2, 3 Low Low, Level 1 S

Q d.

Reactor Vessel Water Level - Low R(*)

I, 2, 3 Low, Level 2 5

Q Suppression Pool Water Level -

S Q

R(

1, 2, 3

[

e.

low Low g

E f.

Suppression Pool Makeup Timer NA Q

Q 1, 2, 3 E

g.

SPMU Manual Initiation NA R

NA 1, 2, 3

(*) Calibrate trip unit at least once per,92 days.

UT 9

REAC10R COOLANT SYSTEM-3/4.4.2 SAFETY VALVES-SAFETY / RELIEF VALVES LIMITING CONDITION FOR OPERATION 3.4.2.1 For the following safety / relief valves:

a.

The safety valve function of at least 7 valves and the relief valve function of at least 6 valves other than those satisfying the safety valve function requirement shall be OPERABLE with the specified lif t settings, and b.

The safety / relief tail-pipe pressure switches for each safety / relief valve shall be OPERABLE.

Number of Valyn Function Setooint* (osio) 8 Safety 1165 11.6 psi 6

Safety 1180 11.8 psi 6

Safety 1190 11.9 psi 1

Relief 1103 15 psi 10' Relief 1113 15 psi 9

Relief 1123 i 15 psi RP.LICABILITY: OPERATIONAL CONDITIONS 1, 2 and 3.

ACTION:

a.

With the safety and/or relief valve function of one or more of the above required safety / relief valves inoperable, be in at least HOT SHUTDOWN within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the next 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , b.

With one or more safety / relief valves stuck open, provided that suppression pool average water temperature is less than 110*F, take action to close the stuck open relief valve (s); if suppression pool average water temperature is 110'F or greater, place the reactor mode switch in the Shutdown

position, c.

With one or more safety / relief tail-pipe pressure switches inoperable, restore the inoperable switch (es) to OPERABLE statur, within 7 days or be in at least HOT SHUTOOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , d.

With either relief valve function pressure actuation trip system "A" or "B" inoperable, restore the inoperable trip system to OPERABLE status within 7 days; otherwise be in at least HOT SHUTDOWN within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

SURVEILLANCE RE0VIREMENTS 4.4.2.1.1 The tail-pipe pressure switch for each safety / relief valve shall be demonstrated OPERABLE ** with the setpoint verified to be 30 5 psig by l

performance of a:

The lift setting pressure shall correspond to ambient conditions of the valves at nominal operating temperatures and pressures.

", A channel may be placed in an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for Initial opening of IB21-F051B is 1103 15 psig due to low-low set function.

required surveillance without placing the trip system in the tripped condition.

GRAND GULF-UNIT 1 3/4 4-5 Amendment No. 49,105

REACTOR COOLANT SYSTEM REACTOR COOLANT SYSTEM SVRVEILLANCE RE0VIR[MENTS a.

CHANNEL-FUNCTIONAL TEST at least once per 92 days, and a l

b.

CHANNEL CALIBRATION at least once per 18 months.*

4.4.2.1.2 The relief valve function pressure actuation instrumentation shall I

be-demonstrated OPERABLE ** by performance of-a:

a.

CHANNEL FUNCTIONAL TEST, including calibration of the trip unit, at least once per 92 days.

l b.

CHANNEL CAllBRATION, LOGIC SYSTEM FUNCTIONAL TEST and simulated automatic operation of the entire system at least once per 18 months.

The provisions of Specification 4.0.4 are not applicable provided the surveillance-is performed within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reactor steam prassure is adequate to perform-the test.

A channel may be placed in an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for required surveillance without placing the trip system in the tripped-condition.

GRAND GULF-UNIT 1 3/4 4-6 Amendment No. 105

. - ~,

.._-.,.___m.

...m_m, 4,

e-y

REACTOR COOLANT SYSTEM LALFTY/REllEF VALVES LQW-LOW SET FUNCTION LIMITING CONDITION FOR OPERATION 3.4.2.2 The relief valve function and the low-low set function of the following reactor coolant system safety / relief valves shall be operable with the following low-low set function lift settings.

Setooint* fosia) t 15 osi yalve No.

Qpan Close F051D 1033 926 F051B 1073 936 F047D 1113 946 F047G 1113 946 F051A 1113 946 F051F 1113 946 APPLICABILITY:

OPERATIONAL CONDITIONS 1, 2 AND 3.

ACTION:

a, With the relief valve function and/or the low-low set function of one of the above required reactor coolant system safety / relief valves inoperable, restore the inoperable relief valve function and the low low set function to OPERABLE status within 14 days or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

b.

With the relief valve function and/or the low-low set function of more than one of the above required reactor coolant system safety / relief valves inoperable, be in at least H0T SHUTDOWN within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the nest 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

c.

With either relief valve / low-low set function pressure actuation trip sys-tem "A" or "B" inoperable, restore the inoperable trip system to OPERABLE status within 7 days; otherwise, be in at least HOT SHUTDOWN within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

SURVEILLANCE RE0VIREMENTS 4.4.2.2.1 The relief valve function and the low-low set function pressure actuation instrumentation shall be demonstrated OPERABLE ** by performance of l

a:

a.

CHANNEL FUNCTIONAL TEST, including calibration of the trip unit, at least once per 92 days.

l l-b.

CHANNEL CALIBRATION, LOGIC SYSTEM FUNCTIONAL TEST and simulated automatic j

operation of the entire system at least once per 18 months.

l

The lift setting pressure shall correspond to ambient conditions of the valves at nominal operating temperatures and pressure.

l

- A channel may be placed in an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for required l

surveillance without placing the trip system in the tripped condition.

GRAND GULF-UNIT 1 3/4 4-7 Amendment-No.105

REACTOR COOLANT SYSTEM 3/4.4.3 REACTOR COOLANT SYSTEM LEAKAGE LEAKAGE DETECTION SYSTEMS LIMITING CONDITION FOR OPERATION 3.4.3.1 The following reactor coolant system.. leakage detection systems shall be OPERABLE:

The drywell atmosphere particulate radioactivity monitoring system, a.

b.

The drywell floor and equipment drain sump level and flow monitoring systems, and Either the drywell air coolers condensate flow rate monitoring system c,

or the drywell atmosphere gaseous radioactivity monitoring system.

APPLICABILITY:

OPERATIONAL CONDITIONS 1, 2 and 3.

ACTION:

With only two of the above required leakage detection systems OPERABLE, opera-tion may continue for up to 30 days provided grab samples of the drywell atmosphere are obtained and analyzed at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months when the required gaseous and/or particulate radioactive monitoring system is inoperable; otherwise, be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTOOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

SURVEILLANCE REQUIREMENTS 4.4.3.1 The reactor coolant system leakage detection systems shall be demon-strated OPERABLE by:

Drywell atmosphere particulate and gaseous monitoring systems-a.

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 , a CHANNEL FUNCTIONAL TEST at least once per 31 da)s and a CHANNEL CALIBRATION at least once per 18 months.

b.

Drywell floor and equipment drain sump level and flow monitoring systems performance of a CHANNEL FUNCTIONAL TEST at least once per 31 days and a CHANNEL CALIBRATION TEST at least once per 18 months.

Drywell air coolers condensate flow rate monitoring system performance c.

of a CHANNEL FUNCTIONAL TEST at least once per 31 days and a CHANNEL CALIBRATION at least once per 18 months.

GRAND GULF-UNIT 1 3/4 4-8

EMERGENCY CORE C00 !NG SYSTEMS l

LlHITING CONDITION FOR OPERATION ACTION: (Continued) c.

With one suppression pool water level instrumentation division inoperable, restore the inoperable division to OPERABLE status within 7 days or verify the suppression pool water level to be greater than or equal to 18'4-1/12" or 12'8", as applicable, at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months by an alternate indicator, d.

With both suppression pool water level instrumentation divisions inoperable, restore at least one inoperable division to OPERABLE status within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months and verify the suppression pool water level to be greater than or equal to 18'4-1/12" or 12'8", as applicable, at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months by at least one alternate indicator.

SURVEILLANCE RE0VIREMENTS 4.5.3.1 The suppression pool shall be determined OPERABLE by verifying:

a.

The water level to be greater than or equal to, as applicable:

1.

18'4-1/12" at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

2.

12'8" at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , b.

Two suppression pool water level instrumentation divisions, with I channel per division, OPERABLE with the low water level alarm setpoint 2 18'51" by performance of a:

l.

CHANNEL CHECK at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , 2.

CHANNEL FUNCTIONAL TEST at least once per 31 days, and 3.

CHANNEL CAllBRATION at least once per 18 months.

c.

Two suppression pool water level instrumentation divisions, with I channel per division, OPERABLE' with the low water level alarm setpoint 2 12'8" per performance of a:

1.

CHANNEL CHECK at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , 2.

CHANNEL FUNCTIONAL TEST at least once per 92 days, and 3.

CHANNEL CAllBRATION at least once per 18 months.

A channel may be placed in an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months during periods of required surveillance provided at least one other OPERABLE channel in the same system is monitoring that parameter.

i GRAND GULF-UNIT 1 3/4 5-9 Amendment No. 105

EMERGENCY CORE COOLING SYSTEMS SURVEllLANCE RE0VIREMENTS (Continued) 4.5.3.2 With the suppression pool level less than the above limit or drained in OPERATIONAL CONDITION 4 or 5*, at least once per 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months s:

a.

Verify the require' conditions of Specification 3.5.3.b to be satisfied, cr b.

Verify footnote conditions

to be satisfied.

GRAND GULF-UNIT 1 3/4 5-10 Amendment No.105

INSTRUMENTATION BASES l

EMERGENCY CORE COOLING SYSTEM ACTUATION INSTRUMENTATION (Continued)

Operation with a trip set less conservative than its Trip Setpoint but within its specified Allowable Value is acceptable on the basis that the difference between each Trip Setpoint and the Allowable Value is equal to or greater than the drift allowance assumed for each trip in the safety analyses.

3/4.3.4 RECIRCULATION PUMP TRIP ACTUATION INSTRUMENTATION The anticipated transient without scram recirculation pump trip (ATWS-RPT) system provides a means of limiting the consequences of the unlikely occurrence of a failure to scram during an anticipated transient.

The response of the plant to this postulated event has been evaluated in General Electric Company report NEDC-32408 cated March 1987.

The results of the analysis show that the Grand Gulf ATVS-RPT design provides adequate protection for these events in whien the normal scram paths fail.

The ATWS-RPT provides fully redundant trip of the recirculation pump motors so that the pumps coast down to zero speed.

This trip function reduces core flow creating steam voids in the core, thereby decreasing power generation and limiting any power or pressure excursions.

The Grand Gulf ATVS-RPT design provides compliance with the requirements of the NRC ATWS Rule 10CFR50.62.

The ATVS-RPT and Alternate Rod Insertion (ARI) system use common set?oints anc trip channels (transmitters and trip systems).

Therefore, the ARI trip function and the RPT trip function will be initiated simultaneously. The instrumentation setpoints for the RPV pressure end water level trip channels are established such that the normal scram paths for these variables would already be initiated.

The End-of-cycle recirculation pump trip (EOC-RPT) system is a part of the Reactor Protection System and is an essential safety supplement to the reactor trip.

The purpose of the EOC-RPT is to recover the loss of thermal margin which occurs at the end-of-cycle.

The physical phenomenon involved is that the void reactivity feedback due to a pressurization transient can add positive reactivity to the reactor system at a faster rate than the control rods add negative scram reactivity.

Each EOC-RPT system trips both recirculation pumps, reducing coolant flow in order to reduce the void collapse in the core during two of the most limiting pressurization events. The two events for which the EOC-RPT protective feature will function are closure of the turbine stop valves and fast closure of the turbine control valves.

A fast closure sensor from each of two turbine control valves provides input to the EOC-RPT system; a fast closure sensor from each of the other two turbine control valves provides input to the second EOC-RPT system.

Similarly, a closure sensor for each of two turbine stop valves provides input to one EOC-RPT system; a closure sensor from each of the other two stop valves provides I

contacts are arranged to form a 2-out-of-2 logic for the fast closure of turbine input to the other EOC-RPT system.

For each EOC-RPT system, the sensor relay control valves and a 2-out-of*2 logic for the turbine stop valves.

The opera-tion of either logic will actuate the EOC-RPT system and trip both recircula-tion pumps.

I GRAND GULF-UNIT 1 B 3/4 3-3 Amendment No. 41.97

(

INSTRUMEN'ATION BASES IEflRCULATION PUMP TRIP ACTUATION INSTRUMENTATION (Continued)

Each E0C RPT system may be manually bypassed by use of a keyswitch which is administratively controlled.

The manual bypasses and the automatic Operating Bypass at less than 40% of RATED THERMAL POWER are annunciated in the control room. The automatic bypass setpoint is feedwater temperature dependent due to the subcooling changes that affect the turbine first stage pressare-reactor power relationship, for RATED lHERMAL POWr.R operation with feedwater temperature greater than or equal to 420', an allowable setpoint of 5 26.9% of control valve wide open turbine first-stage pressure is provided for the bypats function.

This setpoint is also applicable to operation at less than RATED THERMAL POWER with the correspondingly lows.

feedwater temperature.

The allowable setpoint is reduced to s 22.5% of control valve wide open turbine first-stage pressure for RATED THERMAL POWER operation with a feedwater temperature between 370'f and 420*F.

Similarly, the reduced setpoint is applicable to operation at less than RATED THERMAL POWER with the corresponding lower feedwater temperature.

Specified surveillance intervals and surveillance and maintenance outage times have been determined in accordance with General Electric Report GENE 770 06-1, " Bases for Changes to Surveillance Test Intervals and Allowed Out-of-Service Times for Selected Instrumentation Technical Specifications",

february 1991.

The EOC-RPT system response time is the time assumed in the analysis between initiation of valve motion and complete suppression of the electric a r e.,

i.e.,

190 ms, included in this time are:

the response time of the sensor, the response time of the system logic and the breaker interruption time.

Breaker interruption time includes both breaker response time and the manufacturer's design arc suppression time of 12 ms.

Operation with_a trip set less conservative than its Trip Setpoint but within its specified Allowable Value is acceptable on the basis that the difference between each Trip Setpoint and the Allowable Value is equal to or greater then the drift allowance assumed for each trip in the safety analyses.

3/4.3.5 REACTOR CORE ISOLATION COOLING SYSTEM ACTUATION INSTRUMENTATION The reactor core isolation cooling system actuation instrumentation is provided to initiate actions to assure adequate core cooling in the event of reactor isolation from its primary heat sink and the 'oss of feedwater flow to the reactor vessel without providing actuation of any of the emergency core cooling equipment.

4 Specified surveillance intervals and surveillance and maintenance outage times have been determined in accordance with General Electric Report GENE 770-06-2, " Addendum to Bases for Changes to Surveillance Test Intervals and Allowed Out-of-Service Times for Selected Instrumentation Technical Specifications", february 1991.

Operation with a trip set less conservative than its Trip Setpoint but within its specified Allowable Value is acceptable on the basis that the difference between each Trip Setpoint and the Allowable Value is equal to or greater than the drift allowance assumed for each trip in the safety analyses.

3/4.3,6 CONTROL ROD BLOCK INSTRUMENTATION The control rod block functions are provided consistent with the require-ments of the specifications in Section 3/4.1.4, Control Rod Program Controls and Section 3/4.2 Power Distribution Limits. The trip logic is arranged so that a trip in any one of the inputs will results in a control rod block, GRAND GULF-UNIT I B 3/4 3-3a Amendment No. 41, 96, 105

INSTRUMENTATION BASES i

3/4.3,6 CONTROL R0D BLOCK INSTRUMENTATION (Continued) i The OPERABILITY of the control rod block instrumentation in OPERATIONAL CONDITION 5 is to provide diversity of iod block protection to the une-rod-out interlock.

Specified surveillance intervals have been determined in accordance with NEDC-39851P-A, Supplement 1, ' Technical Specification Improvement Analysis for BWR Control Rod Block Instrumentation" as approved by the NRC and documented in the NRC Safety Evaluation Report (letter to D. N. Grace from C. E. Rossi dated September 22,1988). Specified surveillance and maintenance outage times have been determined in accordance with General Electric Report GENE-770-06-1, i

" Bases for Changes to Surveillance Test Intervals and Allowed Out-of-Service Times for Selected Instrumentation Technical Specifications", February 1991, i

1 4

GRAND GULF-UNIT 1 B 3/4 3-3b Amendment No.105_.

.--,,em--.-...--,,%-2--

,,,--.--,--w--s.....

,-----.,,,--_..,mm--

,..er w,,-----

-e w

,m,~--

w,

INSTRUMENTATION BASES 2/4.3.6 CONTROL ROD A OCK INSTRUMENTATION (Continued)

Operation with a trip set less conservative than its Trip Setpoint but within its specified Allowable Value is acceptable on the basis that the difference between each Trip Setpoint and the Allowable Value is equal to or greater than the drift allowance assumed for each trip in the safety analyses.

3/4.3.7 MONITORING 1411MMENTAT10N 3/4.3.7.1 RADIATION MONITORING INSTRUMENTATION The OPERABILITY of the radiation monitoring instrumentation ensures that:

(1) the radiation levels are continually measured in the areas served by the individual channels; (2) the alarm or automatic action is initiated when the radiation level trip setpoint is exceeded; and (3) sufficient information is available on selected plant parameters to monitor and assess these variables following an accident.

This capability is consistent with the recommendations of NUREG-0737, " Clarification of TM1 Action Plan Requirements," November, 1980.

Specified surveillance intervals and surveillance and maintenance outage times have been determined in accordance with General Electric Report GENE-770-06 1,

Bases for Changes to Surveillance Test Intervals and Allowed Out of-Service Times for Selected Instrumentation Technical Specifications",

february 1991.

3/4.3.7.2 SEISMIC MONITORING INSTRUMENTATION The OPERABILITY of the seismic monitoring 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 unit.

3/4.3.7.3 METEQR0 LOGICAL MONITORING INSTRUMENTATION The OPERABILITY of the meteorological monitoring instrumentation ensures that sufficient meteorological data are 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 i

safety of the public.

This instrumentation is consistent with the recommenda-tions of Regulatory Guide 1.23 "Onsite Meteorological Programs " February, 1972.

3/4.3.7.4 REMOTE SHUTDOWN SYSTEM INSTRUMENTATION AND CONTROLS The OPERABILITY of the remote shutdown system instrumentation and controls ensures that sufficient capability is available to permit shutdown and main-tenance of HOT SHUTDOWN of the unit 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 Criterion 19 of 10 CFR 50.

l GRAND GULF-UNIT 1 B 3/4 3 4 Amendment No. 105

INSTRUMENTATION BASES I

3/4.3.7.5 ACCIDENT MONITORING INSTRUMENTATION The OPERABILITY of the accident monitoring instrumentation ensures that sufficient information is available on selected plant parameters to monitor and assess important variables following an accident.

This capability is consistent with the recommendations of NUREG 0578, *TM1-2 Lessons Learned Task Force Status Report and Short-Term Recommendations".

3/4.3.7.6 SOURCE RANGE MONITORS The source range monitors provide the operator with information of the status of the neutron level in the core at very low power levels during startup and shutdown.

At these power levels, reactivity additions should not be made without this flux level information available to the operator. When the inter-mediate range monitors are on scale adequate information is available without the SRMs and they can be retracted.

The SRMs are required OPERABLE in OPERATIONAL CONDITION 2 to provide for rod block capability, and are required OPERABLE in OPERATIONAL CONDITIONS 3 and 4 to provide monitoring capability which provides diversity of protection to the mode switch interlocks.

3/4,3.7.7 TRAVERSING IN-CORE PROBE SYSTEM The OPERABillTY of the traversing in core probe system with the specified minimum complement of equipment ensures that the measurements obtained from use of this equipment accurately represent the spatial neutron flux distribution of the reactor core.

The TIP system OPERABILITY is demonstrated by normalizing all probes (i.e., detectors) prior to performing an LPRM calibration function.

Monitoring core thermal limits may involve utilizing individual detectors to monitor selected areas of the reactor core, thus all detectors may not be required to be OPERABLE.

The OPERABillTY of individual detectors to be used for monitoring is demonstrated by comparing the detector (s) output with data obtained during the previous LPRM calibrations.

}/4.3.7.8 CHLORINE DETEGION SYSTEM DELETED 3/4.3.7.9 FIRE DETECTION INSTRUMENTATION DELETED GRAND GULF-UNIT 1 B 3/4 3-5 Amendment No. B6, BB,105

I INSTRUMENTATION IIASES 3/4.3.7.10 L_@lf-PART DETECTION SYSTEM The OPERABILITY of the loose part detection system ensures that sufficient capability is available to detect loose metallic parts in the primary system and avoid or mitigate damage to primary system components.

The system consists of 16 sensors, of which only 8 are selected and need to be OPERABLE at a time, to provide the inputs to the 8 monitoring channels.

The remaining 8 sensors may be used as replacement sensor inputs for. failed sensors or to provide a change in location of the area being monitored.

The allowable out of-service times and surveillance requirements are consistent with the recommendations of 4

Regulatory Guide 1.133, " Loose Part Detection Program for the Primaru System of Light Water-Cooled Reactors," May 1981.

3/4.3.7.12 MAIN CB DENSER OFFGAS TREATMENT SYSTEM - EXPLOSIVE GAS MONITORING SYSTEM INSTRUMENTATION The explosive gas monitoring system instrumentation of the main condenser off-gas treatment system is provided to monitor the contentrations of potentially explosive gas mixtures in the main condenser offgas treatment system.

This instrumentation is calibrated in accordance with plant procedures.

3/4.3.8 PLANT SYSTEMS ACTUATION INSTRUMENTATION

-The plant systems actuation instrumentation is provided to initiate action to mitigate the consequences of accidents that are beyond the ability of the operator to control.

The LPCI mode of the RHR system is automatically initiated on a high drywell pressure signal and/or a low reactor water level, level 1, signal.

The containment spray system will then actuate automatically following high drywell and high containment pressure signals.

Negative barometric pressure fluctuations are accounted for in the trip setpoints and allowable values specified for drywell and containment pressure-high. A 10-l minute minimum, 13-minute maximum time delay exists between initiation of LPCI and containment spray actuation.

A high reactor water level, level 8, signal will actuate the feedwater system / main turbine trip system.

The suppression pool makeup system is automatically initiated on a low low suppression pool water level signal with a concurrent LOCA signal or following a specified time delay after receipt of a LOCA signal.

The low low-suppression pool water level Trip Setpoint and Allowable Value are relative to the surface floor of the suppression pool (93'01" above mean sea level).

Specified. surveillance intervals and surveillance and maintenance outage times have been determined in.iccordance with General Electric Report GENE-770-06-1, "Bascs for Changes to Surveillance Test and Allowed Out of-Service Times for Selected Instrumentation Technical Specifications", February 1991.

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GRAND GULF-UNIT 1 B 3/4 3 6 Amendment No. 60, 87, 105

l REACTOR COOLANT SYSTEM BASES 3/4.4.2 SAFETY /REllEF VALVES The safety valve function of the sarety/ relief valves (SRV) operate to prevent the reactor coolant system from being pressurized above the Safety Limit of 1325 psig in accordance with the ASME Code. A total of 13 OPERABLE safety / relief valves is required to limit reactor pressure to within ASME 111 allowable values for the worst case upset transient.

Any combination of 6 SRVs operatina in the relief mode and 7 SRVs operating in the safety mode is acceptable.

Demonstration of the safety / relief valve lift settings will occur only during shutdown and will be performed in accordance with the provisions of Specification 4.0.5.

The low low set system ensures that safety / relief valve discharges are minimized for a second opening of these valves, following any overpressure transient.

This is achieved by automatically lowering the closing setpoint of 6 valves and lowering the opening setpoint of 2 valves following the initial opening.

In this way, the frequency and magnitude of the containment blowdown duty cycle is substantially reduced.

Sufficient redundancy is provided for the low-low set system such that failure of any one valve to open or close at its reduced setpoint does not violate the design basis.

Specified surveillance intervals and surveillance outage times have been determined in accordance with General Electric Report GENE-770 06 ', "Pases for Changes to Surveillance Test Intervals and Allowed Out-of-Service 11mes for Selected Instrumentation Technical Specifications", February 1991.

3/4.4.3 REACTOR COOLANT SYSTEM LEAKAGE 3/4.4.3.1 LEAKAGE DETECTION SYSTEMS The RCS leakage detection systems required by this specification are provided to monitor and detect leakage from the reactor coolant pressure boundary.

These systems provide the ability to measure leakage from fluid systems in the drywell.

3/4.4.3.2 OPERATIONAL LEAKAGE The allowable leakage rates from the reactor coolant system have been based on the predicted and experimentally observed behavior of cracks in pipes.

The normally expected background leakage due to equipment design and the detection capability of the instrumentation for determining system leakage was also considered.

The evidence obtained from experiments suggests that for leakage somewhat greater than that specified for UNIDENTIFIED LEAKAGE the probability is small that the imperfection or crack associated with such leakage would grow rapidly.

However, in all cases, if the leakage rates exceed the values specified or the leakage is located and known to be PRESSURE BOUNDARY LEAKAGE, the reactor will be shut down to allow further investigation and corrective action.

Service sensitive reactor coolant system Type 304 and 316 austenitic stainless steel piping, i.e., those that are subject to high stress or that contain relatively stagnant, intermittent, or low flow fluids, requires additional surveillance and leakage limits.

GRAND GULF UNIT I B 3/4 4-2 Amendment No. 105

REACTOR Cf)0LANT SYSTEM BASES

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3/4.4.3.2 OPERATIONAL LEAKAGE (Continued)

The Surveillance Requiren,ents for RCS pressure isolation valves provide added assurance of valve integrity, thereby reducing the probability of gross valve failure and consequent intersystem LOCA.

Leakage from the RCS pressure isolation valves is IDENTIFIED LEAKAGE and will be considered as a portion of the allowed limit.

GRAND GULF-UNIT 1 B 3/4 4-2a _ _ _ _

. Amendment Fo. 105

214.5 EMERGENCY CORI COOLING SYSTEM BASES SUPPRESSION POOL (Continued)

In OPERATIONAL CONDITION 4 and 5 the suppression chamber minimum required water volume is reduced because the reactor coolant is maintained at or belnw 200*F.

Since pressure suppression is not required below 212*F the minimum required water volume is based on NPSH, recirculation volume, and vortex prevention plus a l'2" safety margin for conservatism.

Specified surveillance intervals and surveillance outage times for the wide range suppression pool water level instrumentation have been determined in accordance with General Electric Report GENE-770-06-1, " Bases for Changes to Surveillance Test Intervals and Allowed Out-of-Service Times for Selected Instrumentation Technical Specifications", February 1991.

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GRAND-GULF-UNIT 1 B 3/4 5-3 Amendment No.105 l

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