ML20053C940
| ML20053C940 | |
| Person / Time | |
|---|---|
| Site: | Grand Gulf  |
| Issue date: | 06/01/1982 |
| From: | MISSISSIPPI POWER & LIGHT CO. |
| To: | |
| Shared Package | |
| ML20053C939 | List: |
| References | |
| NUDOCS 8206030196 | |
| Download: ML20053C940 (13) | |
Text
_ _ _ _ _ _
1
>mm
- TABLE 2.2.1-1 Q ].' } g "'.' }
/
EE$
o~
$8 REACTOR PROTECTION SYSTEM INSTRUMENTATION-SETPOINTS O 00
~
ALLOWABLE hN TRIP SETPOINT VALUES
- FUNCTIONAL UNIT
+
o E $$
G oo 1.
Intermediate Range Monitor, Neutron Flux-High
< 120/125 divisions
-< 122/125 divisions E mSo of full scale of full scale
~
{ @p 2.
Average Power Range Monitor:
~
r a.
Neutron Flux-High, Setdown
-< 15% of RATED
~< 20% of RATED THERMAL POWER TIIERMAL POWER
~
~
b.
Flow Biased Simulated Thermal Power-High
- 1) Flow Biased
-< 0.66 W+48%, with
-< 0.06 W+51%,.with a maximum of a maximum of o
- 2) liigh Flow Clamped
-< 111.0% of RATED
-< 113.0%'of RATED THERMAL POWER TifERMAL POWER' c.
Neutron Flux-liigh
-< 118% of RATED
-< 120% of RATED THERMAL POWER THERMAL POWER 7
d.
Inoperative NA NA 3.
Reactor Vessel Steam Dome Pressure - digh 5 1065 psig 5 1080 psig 4.
Reactor Vessel Water Level - Low, Level 3
> 11.4 inches above
-> 10.8 inches above a
~ instrument zero*
instrument zero^
i
< 54.1 inches above
~
5.
Reactor Vescel Water Level-High, Level 8 ~
< 53.5 inches above instrument zero*
instrument zero*
6:
Main Steam Line Isolation Valve - Closure
[6% closed 5 7% closed
~ -
7.
Main Steam Line Radiation - High 5 3.0 x full power 5 3.6 x full power l background background 8.
Drywell Pressure - High
< 1.73 psig 5 1.93 psig 9.
Scram Discharge Vol6me Water Level - liigh 40 * <
of full scale 3
5-a9% f full scale Turbine Stop Valve - Closure 1 40 psig 1 0 psig h,10.
Trip Oil Pressure'- Low 1 44.3 psig 1 41 psig s
NA g
12.
ReactorModeSwitcliShutdownPosition NA 3
j2 13.
Manual Scram NA NA s
rShe Bases Figure B 3/4 3-1.
)
3
~
~
n
--' ''D i "Yf L
i
.y TABLE 3.3.2-2'
- f.,
~
~
~'
E ISOLATION ACTUATION INSTRUMENTATION S'ETPOINTS E
e c3 ALLOWABLE E
TRIP FUNCTION TRIP SETPOINT VALUE h
1.
PRIMARY CONTAINMENT ISOLATION l'
4, h,' '
a.
Reactor Vessel' Water Level -
Low Low, Level 2
^
> -41. 6 inches' * -
> -43.8 inches s-b.
Drywell Pressure - High 5 1.73 psig
$ 1.93 psig c.
Containant and Drywell Ventilation Exhaust Radiation - High
< # r/hr**
mr/hr**
p d.
Manual Initiation-NA NA 2.
MAIN STEAM LINE ISOLATION a.
Low Low Low, Level 1
.3 inches *
.5 inches w
o b.
Main Steam Line Radiation - High
~ ".
full power x full poser l.
.ckground ckground Main Steam Line Prdssup - Low
> 849 psig
> 837 psig c.
d.
Main Steam Line Flow - High 5 169 psid
, 5 176.5 psid e.
Condenser Vacuum - Low
> 9 inches Hg. Vacuum
> 8.7 inches lig. Vacuum f.
Main Steam Line Tunnel Temperature - High
< 180?F**
<.186?F**
g.
Main Steam Line Tunnel A Temp. - High
< 80?F**
< 83 F**
h.
Manual Initiation NA NA 3.
SECONDARY CONTAINMENT ISOLATION Low Low, Level 2 a.
> -41.6 inch'es*
8
> -43.8 inches I
- )
b.
Drywell Pressure - High 5 1.73 psig 1 1.93 psig.
~.
Fuel Handling' Area Ventilation 4,0
%8 k.
c y
Exhaust Radition - High liigh mR/hr**
' <.5d o /hr*
- g.,
s lC d.
Fuel Handling Area Pool Sweep
/t 35 '
W Exhaust P.adiation - High liigh' R/h'r**
$ A& S R/hr**
e.
Manual Initiation NA NA
1
~
P?D3F & EEW COM f
TABLE 3.3.3-2 EMERGINCYCORECOOLINGSYSTEMACTUATIONINSTRUMENTATIONSETPOINTS c,
ALLOWABLE Z
TRIP SETPOINT VALUE TRIP FUNCTION G
A.
DIVISION 1 TRIP SYSTEM ch 1.
RHR-A (LPCI MODE) AND LPCS SYSTEM
> -152.5 inches
=
Reactor Vessel Water Level - Low Low Low, Level 1
> -150.3 inches
- Z a.
b.
Drywell Pressure - High 7 1.89 psig i 1.94 ps'ig
?
5 seconds e.
c.
LPCI Pump A Start Time Delay Relay 55 seconds NA d.
M e dal Initiation NA 2.
AUTOMATIC DEPRESSURIZATION SYSTEM TRIP SYSTEM "A" a.
Reactor Vesse Water Level - Low Low Low, Level 1
> -150.3 inches *
> -152.5 inches 7 1.94 psig b.
Drywell Pressure - High 7 1.89 psig 2 115 seconds E 117 seconds c.
ADS Tiener d.
Reactor Vessel Water Level-Low, Level 3 E 11.4 inches
- i 10.8 inches
_ 145 psig, increasing
[140psig, increasing E
LPCS Pump Discharge Pressure-liigh e.
f.
LPCI Pump A Discharge Pressure-High
> 125 psig, increasing
> 122 psig, increasing SA g.
Manual Initiation 5A
{
B.
DIVISION 2 TRIP SYSTEM w
A 1.
RitR B AND C (LPCI MODE)
Reactor Vessel Water Level - Low Low Low, Level 1
> -150.3 inches *
> -152.5 inches co b.
Drywell Pressure - High 51.89psig 31.94psig a.
LPCI Pump B Start Time Delay Relay 5 5 seconds **
5 5 seconds c.
d.
Manual Initiation NA NA 2.
AUTOMATIC DEPRESSURIZATION SYSTEM TRIP SYSTEM "B" Reactor Vessel Water Level - Low Low Low, Level'1
> -150.3 inches *
> -152.5 inches a.
b.
Drywell Pressure - High 31.89psig 51.94psig 4
c.
ADS Timer
< 115 seconds
< 117 seconds d.
Reactor Vessel Water Level-Low, Level 3 s 11.4 inches
- Inches LPCI Pump B and C Discharge Pressure-High
[125psig, increasing i Wa sig,. increasing e.
ne f.
Manual Initiation NA AA C.
DIVISION 3 TRIP SYSTEM 1.
HPCS SYSTEM Reactor Vessel Water Level - Low Low, Level 2
>-41.6 inches *
<-43.8 inches.'
Q
- b. Drywell Pressure - High 31.89psig 51.94psig h
~~
a.
N c.
Reactor Vessel Water Level - High, Level 8
< 53.5 inches *
< 55.7 inches N
i d.
Condensate Storage Tank Level - Low i 0 inches F -3 inches Suppression Pool Water Level - High 7 5.9 inches 7 6.5 inches g
f.
Manual Initiation NA NA D
e.
-[
, E T i' f M 'P- *; o n p, TABLE 3.3.6-2 l-- _C t.). J R] h u s' t m
CONTROL R0D BLOCK INSTRUMENTATION SETPOINTS z
i i
o g
TRIP FUNCTION TRIP SETPOINT ALLOWABLE VALUE E
1.
R00 PATTERN CONTROL SYSTEM a.
Low Power Setpoint
< 20% of RATED THERMAL POWER
< 20% of RATED THERMAL I'0WER E
b.
Intermediate Rod Withdrawal 7 70% of RATED TilERMAL POWER 7 70% of RATED THERMAL POWER U
Limiter Setpoint y
2.
APRM a.
Flow Biased Neutron Flux-l Upscale
< 0. 66 W + 42%*
< 0.66 W + 45%*
l b.
Inoperative NA NA c.
Downscale 1 5% of RATED THERMAL POWER 1 3% of RATED THERMAL POWER d.
Neutron Flux - Upscale Startup
$ 12% of RATED THERMAL POWER
< 14% of RATED THERMAL POWER 3.
SOURCE RANGE MONITORS w
a.
Detector not full in NA /
t 5
5 1
b.
Upscale
$g 10 cps 10 cp3 w
c.
Inoperative i
N h
d.
Downscale 1 3 cps 1 2 cps 4.
INTERMEDIATE RANGE MONITORS a.
Detector not full in NA NA b.
Upscale
$ 108/125 of full scale
$ 110/125 of full scale c.
Inoperative NA NA d.
D9wnscale 1 5/125 of full scale 1 3/125 of full scale 5.
Llater level-High
$ 32 inches 5 33.5 inches b.
Scram Trip Bypass NA NA 6.
REACTOR COOLANT SYETEM RECIRCULATION FLOW g
- u a.
Upscale
$ 108% of rated flow
$ 111% of rated flow m
1 G
R
^The Average PIER Range Monitor rod block function is varied as a function of recirculation loop flow h-(W).
The trip setting of this function must be maintained in accordance with Specification 3.2.2.
T5 s
.W 9
e
- V l
TABLE 3.3.7.1-1
-. ~ -,, r g {' ] f ' g','[
e RADIATION MONITORING INSTRUMENTATION
[, _ ', ' *
.I.
=
MINIMUM CHANNELS APPLICABLE ALARM / TRIP MEASUREMENT F
INSTR <UMENTATION OPERABLE CONDITIONS SETPOINT RANGE ACTION c3 n
c'-
1.
Component Cooling
?'s Water Radiation 5
6 Monitor 1
At all times il x 10 cpm /NA 1 to 10 ca 70 l
2.
Standby Service Water System Radiation 5
6 Monitor 1/ heat 1, 2, 3, and* 11 x 10 cpm /NA 1 to 10 cpm 70 exchanger train 3.
Offgas Pre-treatment 6
Radiation Monitor 1
1, 2 15 x 10 mR/hr/NA 1 to 10 mR/hr 70 4.
Of fgas Post-treatment 5
6 R'
Radiation Monitor 2(a) 1, 2
-<1 x 10 cpm (Hi),
1 to 10 cpm 71
=
6 11.0 x 10 cpm (Hi Hi) l 5.
Carbon Bed Vault 6
l Radiation Monitor 1
1, 2 5 2 x full power 1 to 10 mR/hr,__ 72___
background /A/A 6.
Control Room Ventila-
-2 2
tion Radiation Monitor 2
1,2,3,5 and**
14 mR/hr/
10 to 10 mR/hr 73 l
~<5 mR/hr#
?
7.
Containment and Drywell Ventilation Exhaust O
-2 2
Radiation Monitor 3(a)
At all times
<2./mR/hr/
10 to 10 mR/hr 74 l
<g mR/hr(b)#
y C
1,2,3,5 and** WRT~ d 4 # g g
8.
Fuel Handling Area f)
-2 2
10 to 10 mR/hr 75 Ventilation Exhaust 3
Radiation Monitor 4 mR/hr(d)#
T-9.
Fuel Handling Area Pool
-2 2
3 Sweep Exhaust Radiation I)
(c)
-HAf d /88
/
10 to 10 mR/hr 75 l
Monitor 3
135 mR/hr(d)#
IN'5TRUMENTATION fh hhb
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TABLE 3.3.7.2-1 SEISMIC MONITORING INSTRUMENTATION MINIMUM MEASUREMENT.
INSTRUMENTS INSTRUMENTS AND SENSOR LOCATIONS RANGE OPERABLE 1.
Triaxial Strong Motic.i Accelerometer
'a '.
Containment foundation 0.001 to 1.0g 1
b.
Drywell 0.001 to 1.0g 1
c.
SGTS Filter Train 0.001 to 1.0g 1
d.
SSW Pump House A 0.001 to 1.0g i
e.
Free Field 0.001 to 1.0g 1
2.
Triaxial Peak Recording Acce'lerograph a.
Containment Dome 0.01 to 2g 1
'b.
Auxiliary Building Foundation 0.01 to 2g 1
c.
Diesel Generator 11 0.01 to 2g 1
d.
Control Building Foundation 0.01 to 2g 1
e.
Control Room 0.01 to 2g 1
f.
Reactor Vessel Support 0.01 to 2g 1
g.
Reactor Recirc. Piping 0.01 to 2g 1
h.
Main Steam Piping 0.01 to 2g 1
1.
LPCS Spray Line 0.01 to 2g 1
3.
a.
Containment Foundation (SSE) 0.025 to 0.25g 1*
b.
Containment Foundation,(0BE) 0.025 to 0.25g 1*
c.
Drywell (SSE) 0.025 to 0.25g 1*
d.
Drywell (OBE) 0.025 to 0.25g 1*
4.
Vertical Seismic Trigger Recorders a.
Containment Foundation 0.005 to 0.05g 1*
5.
Horizontal Seismic Trigger a.
Drywell 0.005 to 0.05g 1*
1 "With control room annunciation.
m GBAND GULF-UNIT 1 3/4 3-61 I 4 l982
.a
kNSTRUMENTATIONe I
l.
~~
O
_ TABLE 4.3.7.2-1 p
SE_ISMIC MONITORING INSTRUMENTATION SURVEILLANCE RE0VIREMENTS -
CHANNEL CHANNEL FUNCTIONAL CHANNEL INSTRUMENTS AND SENSOR LOCATI0t45 CHECK TEST CALIBRATION 1.
Triaxial Strong Motion Accelerometer
'a.
Containment Foundation M
SA R
b.
Drywell M
SA R
c.
SGTS Filter Train M
SA R
d.
SSW Pump House A H
SA R
e.
Free Field M
SA R
2.
Triaxial Peak Recording Accelerograph a.
Containment Dome NA NA R
,,b.
Auxiliary Building Foundation NA NA R
c.
Diesel Generator 11 NA NA R
d.
Control Building Foundation NA
'NA R
e.
Control Room NA NA R
f.
Reactor Vessel Support NA NA R
g.
Reactor Recirc. Pipicc NA NA R
h.
Main Steam Piping NA NA R
i.
LPCS Spray Line NA NA R
' v NPGS S i
SS W ump those R x.L9 44 A_
3.
a.
Containment Foundation (SSE)
M SA R
b.
Containment Foundation (0BE)
M SA R
c.
Drywell (SSE)
M SA R
d.
Drywell (OBE)
M SA R
4.
Vertical Seismic Trigger Recorders a.
Containment Foundation M
SA R
,' 5.
' Horizontal Seismic Trigger a.
Drywell M
SA R
MAY 141982 GRAND GULF-UNIT 1 3/4 3-62
l s
.... ~.
4. -,.
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(1% Ll'.A 5....'.L. k.'4 INSTRUMENTATION V
/5 RADI0 ACTIVE LIQUID EFFLUENT MONITORING INSTRUMENTATION t
LIMITINGCONDITIONFORCPERATION 3.3.7.11 The radioactive liquid effluent monitoring instrumentation channels shown in Table 3.3.7.11-1 shall be OPERABLE with their alarm / trip setpoints set,to ensure.that the limits of Specification 3.11.1.1 are not exceeded.
The al,arr ints of these channels shall be determined in accordance with th 1culation Manual (00CM).',
APPLICABILITY:
At all times.
l ACTION:
a.
With a radioactive liquid effluent monitoring instrumentation channel alarm / trip setpoint less conservative than required by the above specification, immediately suspend the release of radioactive liquid effluents monitored by the affected channel or declare the channel inoperable.
b.
With less than the minimum number of radioactive liquid effluent monitoring instrumentation channels OPERABLE, take the ACTION shown in~ Table 3.3.7.11-1.
Restore the inoperable instrumentation to OPERABLE status within the time specified in the ACTION or explain
\\--
why this inoparability was not corrected in a timely manner in the next Semiannual Radioactive Effluent Release Report.
l c.
The provisions.of Specificaticas 3.0.3, 3.0.4 and 6.9.1.11 are not applicable.
t l
.iURVEILLANCE REQUIREMENTS
,4.3.7.11 Each radioactive liquid effluent nionitoring instrumentation channel shall be demonstrated OPERABLE by performance of the CHANNEL CHECK, SOURCE
' CHECK, CHANNEL CALIBRATION and CHANNEL FUN &TIONAL TEST operations at the frequencies shown in Table 4.3.7.11-1.
l4
, GRAND GULF-UNIT 1 3/4 3-81 MR 7 1982 S
m
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TABLE 3.3.8-2 l
E.
PLANT SYSTEMS ACTUATION' INSTRUMENTATION SETPOINTS o
c-ALLOWABLE G-TRIP FUNClION c'-
TJtIP SETPOINT,
VALUE 5,
1.
CONTAINMENT SPRAY SYSTEM
~
H a.
Drywell Pressure-High' i 1.89 psig i 1.94 psig b.
Containment Pressure-High 1 9 psig.
5 9.2 psig c.
Reactor Vessel Water Level-Low Low Low, Level 1
> - 150.3 inches
> - 152.5 inches d.
Timers
~
- 1) System A'
< 10 minutes
< 10 minutes
- 2) System B 311.5 minutes 511.5 minutes 2.
FEEDWATER SYSTEM / MAIN TURBINE TRIP SYSTEM u
57.7 1
a.
Reactor Vessel Water Level-High, Level 8 5 53.5 inches
- 1 nches m
d W
^See Dases Figure B 3/4 3-1. I m
m 4
A Q
/}p/0f/3 CONTAINMENT SYSTEMS' AOn? O nD."1,'lu 07,9 n m IX tL.v u bv i g
3/4.6.3 DEPRESSURIZATION SYSTEMS SUPPRESSION P00 LIMITING CONDITION FOR OPERATION 3.6.3.1 The suppressio all be OPERABLE with the pool water:
/ r,.te 3
and 138,851 ft, equivalent to a level a.
Volume b e
1%,~
t3 g
,a 1 '10", and a betwee b.
Maximum o m a e temperature of 95?F during OPERATIONAL CONDITION.1 or 2, except that the maximum average temperature.may be permitted to increase to:
1.
105?F during testin; which adds heat to the suppression pool.
- 2., 110?F with THERMAL POWER'less than'or eg'ual to 1% of RATED THERMAL POWER.
3.
120?F with the main steam line isolation valves clo' sed following a scram.
APPLICABILITY:
OPERATIONAL CONDITIONS 1, 2 and 3.
ACTION:
'With the suppression pool water level outside the above limits, a.
restore the water level to within the limits within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
b.
In OPERATIONAL CONDITION 1 or 2 with the suppression pool average water temperature greater than 95?F, restore the average temperature to less than or equal to 95?F within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, except, as permitted above:
1.
With the suppression pool average water temperature greater than 105?F during testing which adds heat to the suppression pool, stop all testing which adds heat to the suppression pool and restore the average temperature to less than 95?F within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
~
2.
With the suppression pool average water temperature greater than 110 F, place the reactor mode switch in the Shutdown position and operate at least one residual heat removal loop in the suppression pool cooling mode.
3.
With the suppression pool average water temperature greater than 120?F, depressurize the reactor pressure vessel to less than 200 psig within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.
- ee Specification 3.5.3 for ECCS' requirements.
(.m S
GRAN0' GULF-UNIT 1 3/4 6-20 iMAR 31 1982
~
M 8
e EMERGENCY CORE COOLING SYSTEMS
,7 I',a..IL'..'....'..;
k LIMITING COND'. TION FOR OPERATION (Continued)
~ ~ ~ ~ ' ' ~ ~ ' " ' '
ACTION: (Continued)
/. %'
c.
With one suppression pool water level instrumentation division inoperable, restore the i operable division to OPERABLE status within 7 days or verify the suppression pool water level to be greater than or equal to 4P5"or 12'8", as applicable, at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 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 <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> and suppression pool water level to be greater than or equal ri 4,3/[ to r 12'8", as applicable, at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> by at st one alternate :qdicator.
SURVEILLANCE REOUIREMENTS 4.5.3.1 The suppression pool shall be determined OPERABLE by verifying:
a.
The 1 to be greater than or equal to, as applicable:
jg't/%"
\\
1.
-14'-53 t least once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
2.
12'5" at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.
l b.
Two suppression pool water level instrumentation divisions, with 2 channels per division, OPERABLE with the low water level alarm setpoint > 18'5\\" or 12'8", as applicable, by performance of a:
l 1.
CHANNEL CHECK at least once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, 2.
CHANNEL FUNCTIONAL TEST at least once per 31 days, and 3.
CHANNEL CALIBRATION at least once per 18 months.
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 <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />s:
a.
Verify the required conditions of Specification 3.5.3.b to be satisfied, or b.
Verify footnote conditions
- to be satisfied.
N GRAND GULF-UNIT 1 3/4 5-9 APR 151982i
..a--
a--..~----
h U fI3 e
0:'"0N"I* U '501ii.' p m' 0 P'""Nu ELECTRICAL POWER SYSTEMS 35
.:b f i' REACTOR PROTECTION SYSTEM ELECTRIC POWER MONITOR:f?O--
s
. LIMITING CONDITION FOR OPERATION Two RPS electric power monitoring assemblies for each inservice RPS 3.8.4.4 MG set or alternate power supply shall be OPERABLE.
APPLICABILITY:
At all times ACTION:
With one RPS electric power monitoring assembly for an inservice RPS MG a.
set or alternate power supply inoperable, restore the inoperable power monitoring system to OPERABLE status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or remove the associa.ted RPS MG set or alternate power supply from service.
With both RPS electric power monitoring assemblies for an inservice RPS MG b.
set or alternate power supply inoperable, restore at least one electric power monitoring assembly to OPERABLE status within 30 minutes or remove the associated RPS MG set or alternate power supply from service.
\\
SURVEILLANCE REQUIREMENTS The above specified RPS electric power monitoring assemblies shall be 4.8.4.4 determined OPERABLE:
At least once per six months by performance of a CHANNEL FU a.
TEST, and At least once per 18 months by demonstrating the OPERABILITY of b.
over-voltag.e, under-voltage and under-frequency protective instrumentation by performance of a CliANNEL CALIBRATION including simulated automatic actuation of the protective relays, tripping i
logic and output circuit breakers and verifying the following setpoints:
l 1.
Over-voltage 5,132 VAC, 2.
Under-voltage > 117 VAC, and 3.
Under-frequency >, k Hz 57
~.
M 3 ; ;ggg GRAFD GULF-UNIT 1 3/4 6-46
/.3 wl0 RADI0 ACTIVE EFFLUENTS
" ' ' p. m,r
-.-~-e nn-r,(
LIOUID WASTE TREATMENT
, I.,, /
'TI LIMITING CONDITION FOR OPERATION 3.11.1.3 The liquid radwaste system components as specified in the '00CH shall be OPERABLE.
The appropriate portions of the system shall be used to reduce the radioactive materials in liquid wastes prior to their discharge when the cumulative projected dose due to the liquid effluent from the site (see Figure 5.1.4-1) in a 31 day period would exceed 0.06 mrem to the total body
,4 or 0.2 mrem to,any organ.
APPLICABILITY:
At all times.
i-ACTION:
With the liquid radwaste treatment system inoperable for more than
.a.
31 days or with radioactive liquid waste being discharged without treatment and in excess of the above limits, in lieu of any other report required by Specification 6.9.1, prepare and submit to the s
Commission within 30 days pursuant to Specification 6.9.2 a Special Report which includes the following information:
1.
Identification of the inoperable equipment or subsystems and l..,
the reason for inoperability, 2.
Action (s) taken to restore the inoperable equipment to OPERABLE status, and 3.
Summary description of action (s) tak$n to prevent a recurrence. l b.
The provisions of Specifications 3.0.3, 3.0.4 and 6.9.1.11'are not l 'l applicable.
t l '.
SURVEILLANCE REQUIREMENTS i
s 4.11.1.3.1 Doses due to liquid releases to unr'estricted areas shall be i
- ' " " % t least once per 31 days, in accordance with the ODCM.
4.1
.2 The liquid radwaste system components specified in the ODCM shall be demonstrated OPERABLE by operating the liquid radwaste treatment system equipment for at least 30 minutes at least once per 92 days unless the liquid radwaste system has been utilized to process r.dioactive liquids during the previous 92 days.
FEB 1 1982 l,
GRAND GULF-UNIT 1 3/4 11-6 h w.en.
o m.
.