ML20127L618
| ML20127L618 | |
| Person / Time | |
|---|---|
| Site: | Vogtle  |
| Issue date: | 06/20/1985 |
| From: | Bailey J GEORGIA POWER CO. |
| To: | Adensam E Office of Nuclear Reactor Regulation |
| References | |
| RTR-REGGD-01.097, RTR-REGGD-1.097 NUDOCS 8506280071 | |
| Download: ML20127L618 (22) | |
Text
Georgia Power Company Project Mt.nagement.
Routa 2. Box 299A Waynesboro. Georgia 30830 ~
Telephone 404 724-8114 404 554 9961 Southern Company Services, Inc.
Post Office Box 2625 C"20!#"*e,5202 Vogtle Project a
June 20, 1985 Director of Nuclear Reactor Regulation File:
X7BC35 Attention: Ms. Elinor G. Adensam, Chief Log:
GN-646 Licensing Branch #4 Division of Licensing U. S. Nuclear Regulatory Commission Washington, D. C.
20555 REF: Novak to Foster, dated 5/15/85 NRC DOCKET NUMBERS 50-424 AND 50-425 CONSTRUCTION PERMIT NUMBERS CPPR-108 AND CPPR-109 V0GTLE ELECTRIC GENERATING PLANT - UNITS 1 AND 2 REQUEST FOR ADDITIONAL INFORMATION:
DSER OPEN ITEM 62
Dear Mr. Denton:
In the referenced letter your staff has requested additional justification and/or clarification on the VEGP conformance to Regulatory Guide 1.97, Revision 2.
Enclosed please find our response to the referenced letter.
If your staff requires any additional information, please do not hesitate to contact me.
Sincerely,
.h-J. A. Bailey Project Licensing Manager JAB /wkl Enclosure xc:
D. O. Foster R. A. Thomas J. E. Joiner, Esquire B. W. Churchill, Esquire M. A. Miller B. Jones, Esquire, w/o Encl.
L. T. Gucwa G. Bockhold, Jr.
H. H. Gregory, III T. Johnson, w/o Encl.
/
/, 8g6 D. C. Teper, w/o Encl.
L. Fowler Vogtle Project File
//
il 8506280071 850620 ADOCK050g4y4 DR
l.
Reactor Vessel Water Level - Item 3.3.1 The applicant states that the reactoi vessel water level system was procured as a fully qualitied system, i.e.,
meeting Category 1 criteria.
In Table 7.5.2-1 and 7.5.3-2, the system is so classified by the applicant.
This conflicts with the Category 2 classification of the system in note 1 of Table 7.5.2-1.
The applicant should clarify his position on the system category.
Response
Table 7.5.2-1 will be revised in amendment 17 as shown in the attached annotated copy of the table.
The reactor vessel water level system conforms to Regulatory Guide 1.97, Rev.
2.
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2.
Containment Isolation Valve Status - Item 3.3.2 Category 2 instrumentation has been provided for this variable by the applicant instead of the recommended Category 1 instrumentation.
The applicant states that for isolation valves in series, a single indication on each valve is sufficient to satisfy the requirements of l
Regulatory Guide 1.97 when those indications are from different trains.
The applicant should clarify whether the only reason for a l
system classification of Category 2 is because of a single l
valve indication or whether there are additional reasons i
for the Category 2 classification.
If there are other i
deviations from Category 1, they should be justified.
Response
Containment isolation valve status conforms to Regulatory Guide 1.97, Rev. 2 Category 1 instrumentation criteria, except for single valve indication.
There are no other deviations from the Category 1 criteria.
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3.
Pressurizer Heater Status - Item 3.3.3 l
The applicant does not follow Regulatory Guide 1.97, in that pressurizer heater breaker position instead of heater current is provided for monitoring the pressurizer heater status.
The applicant states that breaker position is adequate because a) Plant Vogtle emergency operating procedures (EOP's) use heater breaker position for verifying the heaters availability and for postulated shorts, the circuit breakers would trip providing isolation, b)
Section II.E.3.1 of NUREG-0737 requires Plant Vogtle to have two pressurizer heater banks be capable of being loaded on the emergency diesel generators, c) The EOP's instruct operators to utilize heater breaker position to verify heaters are engaged, and d) the pressurizer pressure, the core exit thermocouples and the RCS subcooling instrumentation provide indication of heater performance.
We find these justifications unacceptable.
Pressurizer heater breaker position does not monitor heater operation and for postulated shorts, 1
tripping of the breaker is its design funct. ion.
Monitoring of the current provides indication of both.
The proposed alternate means of monitoring do not provide clear, direct, or immediate indication of pressurizer i
heater operation.
Response
The precourizer heaters are not required to mitigate the consequences of an accident.
The VEGP Emergency Operat.ing Procedures during recovery from an accident allow the operator to energize the pressurizer heaters to maintain the pressurizer ~prossure stable, if they are available.
The heaters may be loaded onto the emergency-diesel generators in the event of loss-of-offsite power.
To verify that the' heaters are engaged the operators are directed to check'the breaker status lights.
- However, verification of pressurizer heater performance is by pressurizer pressure, core subcooling and/or core exit thermocouples.
If any of these parameters (i.e.
pressurizer pressure, core subcooling or core exit thermocouples) are not within the specified limits, the procedures instruct the operators to take the appropriate steps.
In addition to breaker position, the following instruments are available to theLoperator to determine the status of the pressurizer heaters.
pressurizer heater overload breaker trip alarm in the e
control room e
us undervoltage alarm in the control room 3
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e local ammeter at switchgear in control building of the bus current (pressurizer heater load is approximately 1/3 of the bus load) e local voltmeter at switchgear in control building of the bus voltage During normal operation, as required by the technical specifications, the capacity of each group of the pressurizer heaters will be verified by energizing the heaters and measuring the circuit current at least once per 92 days.
Because the pressurizer heaters are not required to mitigate the consequences of an accident and monitoring pressurizer heater current in the control room will not enhance the safety of the plant, the addition of pressurizer heater current instrumentation is not justified.
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4.
Accumulator Tank Level and Pressure - Item 3.3.4 The applicant specifies that both the accumulator tank level and pressure instrumentation have been downgraded from a Category 2 Type D to a Category 3 Type D variable.
The applicant states that a) the wide range RCS pressure is the primary post-accident monitoring variable for monitoring the status of the accumulator pressure, b) the plant EOP's utilize the wide range RCS pressure to determine the status of accumulator pressure and accumulator isolation, c) the RCS subcooling, the steam generator pressure and the RCS hot leg temperature instrumentation provide a determination of accumulator isolation, and d) the range of the installed accumulator pressure transmitter is 5% above the safety setpoint of the accumulator safety valve.
Therefore, downgrading the accumulator pressure instrumentation to Category 3 is justified.
In addition, accumulator isolation valve position indication and monitoring of the accumulator vent valves, is considered by the applicant justification for downgrading the accumulator tank level instrumentation to Category 3.
We find these justifications unacceptable, In accident conditions Category 3 instrumentation is considered to have failed.
In the event that RCS pressure drops to the pressure that would cause the accumulator to discharge, there would be no direct indication to confirm operation of the accumulator and would not show a discharge that is discernable from the operation of the HPI or LPI.
The applicant has still not provided justification for the range deviation for the accumulator pressure instrumentation.
Response
(
The accumulators are designed to passively inject water into the RCS when the primary pressure falls below the accumulator cover gas pressure '(564 to 637 psig per Technical Specification 3.5.1.d).
The nitrogen cover gas l
would not be injected until much lower pressures are l
reached.
Since the discharge of water from the accumulators is beneficial for' transients resulting from RCS breaks, the accumulator discharge valves are locked open and cannot be opened from1the control room.
Subsection 15.6.5 provides RCS depressurization curves for various size LOCAs.
The accumulators inject water for the large and small LOCAs analyzed.
If the operator had determined that there is no further l
need or potential need for accumulator water injection and he desired to preclude the addition of nitrogen during the long-tern LOCA recovery phase and if the RCS pressure had not dropped below 600 psig, the operator may vent the 5
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accumulators and/or isolate the discharge of the accumulators by directing the power breakers to be unlocked (outside the control room), provided that this action would not violate any procedures.
If water has been injected, it was needed or at least not adverse to the core.
Should there be a question as to whether the accumulators actually discharged nitrogen into the primary system, the operator could utilize the pressurizer and reactor vessel level indication to determine if nitrogen was in the pressurizer or the vessel head.
These areas can be vented from the control room, if it is deemed appropriate.
For events that do not result in RCS depressurization transients the operating staff will isolate or depressurize the accumulators prior to proceeding to a cold shutdown condition.
The operating staff has two variables available to them to indicate the successful completion of this action:
valve position of the accumulator discharge valves and valve position of the nitrogen vent valves.
The operator is capable of isolating or depressurizing the accumulators even with an assumed single failure.
Therefore, the accumulator level and pressure indications are unnecessary for these events as well as a LOCA.
The range of the accumulator tank pressure transmitter is adequate to monitor any expected pressure in the accumulator.
The maximum pressure allowed by the plant Technical Specification is 637 psig.
The two check valves in the discharge line from each accumulator prevent fluid l
addition to the tank following an accident.
Therefore, i
there is no need to cxtend the pressure indication beyond the present 700 psig range.
The recommended range of level indication from 10 to 90 percent of tank volume is unnecessary.
The level transmitters are used for technical specification surveillance.
The plant Technical Specifications require that the content of the tank be maintained within a very narrow range (6616 to 6854 gallons).
The instrumentation provided monitors the level of the tank for a span of 14 inches (from 59 to 66 percent of tank volume) in which the normal level is maintained.
Accumulator isolation valve position (HV-8808A, B, C and D), accumulator vent valve position (HV-8875A, B, C,
header vent valve D,-E, F,
G, and H), accumulator N2 position (HCV-943A and B) and wide range RCS pressure provide the operator adequate information to monitor the status of the accumulators.
Because the operator would not use accumulator tank pressure or level in making decisions to mitigate the consequences of an accident upgrading the instrumentation to Category 2 is not justified.
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5.
Accident SanDlino - Item 3.3.8 Section 9.3.2.2.5 states that the accident instrumentation is provided and meets TMI Action Plan Task II.B.3.
However, a determination of conformance to R. G.
1.97 cannot be provided until the information requirements of Section 6.2 of NUREG-0737, Supplement No. 1 have been provided in Table 7.5.2-1.
Response
Table 7.5.2-1 will be revised in amendment 17 to provide the information requirements of Section 6.2 of NUREG-0737, Supplement No. 1 as shown on the attached annotated copy of the table.
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6.
RCS Soluble Boron Concentration. Radioactivity Concentration or Radiation Level in Circulatino Coolant and Analysis of Primary Coolant (Gamma Spectrum)
These three variables have been identified by the applicant as part of the post-accident sampling system, however, until the information requirements of Section 6.2 of NUREG-0737, Supplement No. I have been included in Table 7.5.2-1, it cannot be determined that the requirements of Regulatory Guide 1.97 have been met.
Response
Table 7.5.2-1 will be revised in amendment 17 to provide the information requirements of Section 6.2 of NUREG-0737 Supplement No. 1 as shown on the attached annotated copy of the table.
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7.
Reactor Coolant Pump Status 1.ie applicant has not provide 6 justification for providing l
pump breaker position instead of the recommended motor current for the range.
Dependent on the accident conditions, the reactor coolant pumps may or may not be operating.
When they are operating, the motor current is a valuable aid to the operator in diagnosing approach to cavitation, pump seizure, and shaft break conditions.
This information can be valuable in mitigating the consequences of an accident.
Response
l The VEGP Emergency Operating Procedures do not utilize I
motor current to assess the operation of the reactor coolant pumps, but rather the reactor coolant pump breaker positions are used.
Therefore, the reactor coolant pump breaker position has been classified as a Type D, Category 2 variable in table 7.5.2-1.
Reactor coolant pump motor current is available in the control room via the emergency response facility computer CRT display.
The motor current range is 0-400 amps.
This current instrumentation conforms to the Regulatory Guide 1.97, Rev 2 requirements for Category 3 instrumentation.
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8.
Pressurizer Relief Tank Temperature The applilant has specified that their range for pressurizer relief tank temperature instrumentation is 50 to 300*F, while Regulatory Guide 1.97 recommends 50 to 750*F.
The applicant has not provided justification for this deviation.
The applicant chould provide justification for not complying with the Regulatory Guide 1.97 specified range of 50 to 750*F for th9 pressurize relief tank temperature instrumentation.
Response
The pressurizer relief tank (PRT) temperature range is adequate to monitor any expected conditions in the tank.
For the design basis pressurizer steam discharge, the PRT water temperature is maintained below 200*F.
(refer to subsection 5.4.11).
The VEGP Emergency Operating Procedures direct the operator to check if the PRT temperature is less than 115'F to determine if there is an ongoing loss of RCS inventory via leakage to the PRT.
Once the temperature exceeds ll5'F. the operator monitors PRT pressure to determine if the rupture disk has opened.
If a discharge results in a pressure that exceeds the design, the rupture discs on the tank would pass the discharge through the tank to the containment.
The rupture disc release pressure is 91 psig, nominal.
Following breach of the disc, the temperature of the tank will not exceed the saturation temperature associated with the existing containment pressure.
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- 9.
Hich Level Radioactive Liquid Tank Level and Radioact.ive Gas Holdup Tank Pressure.
The applicalit has indicated that these two variables provide indication and alarms in the control room, however, until the information requirements of Section 6.2 of NUREG 0737 Supplement No. 1 have been included in Table 7.E.2-1, it cannot be determined that the requiremenits of Regulatory Guide 1.97 have been met.
Response
Table 7.5.2-1 will be revised in amendment 17 to provide the information requirements of Section 6.2.of NUREG-0737, Supplement No.
1, as shown on the attached annotated copy of the table.
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10.
Auxiliary Building Radiation Level - (Portable Monitorina)
The applicant has deviated both in iategory and range.
A Category 3 instead of the recommended Category 2 has been specified for the instrumentation.
No range has been specified for the instrumentation.
The applicant has not provided justification for the deviations.
The applicant should comply with Regulatory Guide 1.97 by providing Category 2 auxiliary building radiation level instrumentation and provide justification for not complying with the specified range of 10-1 to 104 R/hr for the auxiliary building radiation level instrumentation.
R_esponse The non-containment area monitors originally specified as j
a part of-the process and effluent radiation monitoring system have been redesignated as Type E, Category 3 post accident monitors (see Table 7.5.2-1 sheets 8 and 8A).
While the ranges of these monitors have not been expanded or increased, they provide usable surveillance data.
It should be noted that Revision 3 of Regulatory Guide 1.97 has reclassified this variable as Category 3.
(
Because post-accident servicing of safety-related equipment is not expected immediately after an accident, permanently installed area monitors have not been provided.
Because of the variable nature of maintenance i
requirements post-accident, plant health physicists equipped with portable monitors will precede personnel to any areas where radiation may. restrict access to service safety-related equipment.
Portable radiation survey instrumentation with the capability to detect gamma radiation over the range of 10-1 to 104 R/hr will be maintained at the health physics station (see Table 12.5.2-2).
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General Ouestions a)
Does the applicant intend to specify in Table 7.5.2-1 that the containment effluent radioactivity instrumentation, the accumulator isolation valve status instrumentation, and the emergency ventilation damper position instrumentation is included as part of other variables listed in Table 7.5.2-17 b)
Did the applicant have any specific reason for changing the variable type for the control rod position indication instrumentation from B to D?
Response
a)
Table 7.5.2-1 will be revised in amendment 17 to address the above items as shown on the attached annotated copy of the table.
b)
VEGP defines Type B variables as those that provide to the control room operating staff information to assess the process of accomplishing or maintaining the critical safety functions defined in the VEGP Emergency Operating Procedures, i.e.,
subcriticality, core cooling, heat sink, reactor vessel integrity, containment environment and core inventory.
Control rod position is not utilized to monitor any critical status tree in the VEGP Emergency Operating I
Procedures, hence, it is not classified as a Type B variable.
Instead, control rod position is used to monitor the status of the rod control system, i.e.,
a system normally employed for attaining a safe shutdown condition.
Thus, control rod position is classified as a Type D variable instead of a Type B l
variable based upon the definitions setforth in l
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TABLE 7.5.2-1 (SHEET 3 OF 11)
Ameegse/
t ysse*/
In%ee s t riret tese.
themseer af MM It&hlit Ef1499G 188'MPl. EEigetig,,,, pop 14,,,,,
,Jted,Lckgipeg,
_tgg g_
gh.At h v l e esse.
taptemen.
toest en.
Powe 8:eeestreeg stense te t tese 3eep.r (Or Itc neest.,
.e0 e se see se, C2 v..
v..
2 per uait eas e es. pier Core sees h
- "7 gesedles. Goodles.
{e".*see**
ic vs.
vs.
fCoaler,es 1.
16
)
e to Reg GaA l.97, percent i
resener I OW O vesnes height centesament open sensessen velve eseee/
C2, op ves ves e par t pa e r er d
statee a tehts per Complete at vos vos gel wesve Centelammet S te le Si, C4 Vos Yes 2 per unit 2 meters voswe Iweresse percent Eg16 geneestratism parties prestere 4 does t Complete St Yes Yet Conferes to recorder Centelmeest aS to 160 Cf. C2 vos Yes 2 per unit seg casede 3,9F, Rev 2 presseste i
testensee 94i9 reasel
~
Pseene desplay Core seed it Yes vos tenterms to Ae9 Ceside 1
(4 i.)4 e a.t t.
C2, r2 v.e v..
t,er esait 3..,.
O t 97, nov 2 n
ie,e.
ic.C ies reessess Core io
.e..it v..
vs.
'13 es.nesse.ca t a ea 1
C
- r. -
PIsot weet per* EIA ceasese noe sees t.
4, 48cesiste6 esed C2, f 2 vet vet 8th helegen (pse-IDA 1.97, nov 2 m
elwe (Illerel Ceeplete NA IIA E4 y
Conferee to asset e s Seg Goede M
3
= ass ses.a.ry e4 c3 ase no mA 1.yF, nov 2 I
redletten towel see 4
1 teertabte Ceeptete mA 44 est seepting) ceareres to E
nos sala Site empiren.
mA I.97, Aev 2 P16 sentes C3, E3 * 'Be No 8tA l
reeletlen Gewet ISA (porteDie Complete un AA 44 sag ttag) conferee te Reg Capees 3.pF, Asv 2 acs actswsty see C3 me as s
4 a
ts,o,ot seeseen --- -- -
Pass y
g gg A - - -
Ceeptete mA vos Yes tel
.. e4 n w ru
- ... =,
11
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A >=* W
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1 TABLE 7.5.2-1 (SHEET 5 OF 11) er tec s.s ssee.
1 e. s a.rstas e.w..
m.*r er empere n.
c nn.c s
ens.ca.
e
.t.
c er e n e t.t.
s..p.
s..
n4
/
syp p versense statue cetee.uy.ac.aleL Ethelg _serta _
enseretsen note a!L 11e11
_Liset Geefersease stese senereter o to S er vos vos 2 per e meters campsete seen.tg vos veo concerse se eye eses e recereere ers aeg susee ans.l.se steene w sh/s.sen
.s.t.res t yF, pov 2 stese es s*.w.at r se se seesweser apen/
up veo vos e par see,
- a. peer er composte et vos vee (e3 s,nts per centres veswo eseeed weeve stesse sensa reesheter open/
at vos vos a per see, t pe e r er campsete it vee vos (el myeens vesve esoned e.gnts per vesve states M
see 2 per e meters campiete seen.t t vee vos centerne to e recereers ups cosee 16 e to S er ves sensa. reeduster
.s.t.ee
".lF,osv2 res
.sision i
nerei.e seini
- stese sonorater open/
er ves vos e per I peer er complete It ves vos top sie ts per n
misusewn eseeed vesve weeve seesessen weswo a
l1b statue Cl steen senereter esen/
se vos vos e per a peer er campsete it vos vee gej
'O esse seesessen eseeed steem esents per e
weswe veswe esesee
'vj l
sesos sised a to tese er ves ves a per unit a meter complete it vos vee centeres te gf3 see sweee y
serety ges/ son 3.g7, pov 2 anJoctaen tow-sieed e to see er vos ves 4 per 2 meters complete it vos vos centerne to 8
4 seroty gesteen train noe swede ggg f.97. mov 2 anjectsen sensa ressesser open/
er vos vos a ser I pe e r er coepsete it vee vos get seesessen we weeve esente per wesee statue reereoney ce
/
at vos vee I per 8 peer er complete it vee vos get eessing syst esseed weeve siente per vesve vesve etetes ace.musster o to 7ee et set me a per tonn a meters core sees non-st ves vos tog l16 ups pressere pess l16 ser.tr njee. ent.rr er ve.
vos a per pump i peer er campseie it vos v..
ad, s
e sgnts per seen pump peep state.e D
On slh b
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I TA"LE 7.5.2-1 (SHEET 7 OF 11) i en_1MiqalloJL, IIueber or iopIemen-Power fOr iSC Range /
lype/
nw ron-Instru-Control Room tation Sup-Indica-Indica-ya ((a M g 11p3.gg Gptegg.cy _sentaI
$eipe1c _meny
_indfsmilon.
Jie pIy tien llL Conroranrics shclear service o to or Yes'"
Yes a per 2 meter Complete Ison-t E Yes Yes idl 16 l
cooling water so.nno t ra in urs system flow gal / min Ihclear service Open/
D2 Yes Yes per I pair or Complete IL Yes Yes (d) cooling water closed valve Ilghts per valve status valve l
IInclear service en/orr 92 Yes Yes 1 per pump t pair or Complete it Yes Yes (di cooling water lights per pesey atatus pteep leeclear service On/off D2 Yes Yes I per ran I pair or Complete IE Yes Yes (d) cooling water Ilghts per ran status ran Ites t ing.
Open/
D2 Yes Yes I per I pair or Complete 1[
Yes Yes (dl ventilatlen, caesed deeper IIghts per h
anel air-con-deeper p
ditioning g
g system stat g
M l}g rnginenrod Illgh/ low D2 Yes Yes a per ESF l alare per Complete IE Yes Yes (d, n) gn safety component channel y
rea tie res. l E ST )
W envirennent I
tempera ture Q
EST environ-Open/
D2 Yes Yes I per ESr I pair of Complete IE Yes Yes (d) sont cooler closed component IIghts per ran status channel Ac, dc. wital Seas 02
- Yes, Yes 1 per bass 1 meter per Complete IE Yes Yes Conforms to innt ressent speclric bus lleg Golde f
voltage 1.9T, Rev 2 Residual heat gel
- to D2 Yes
.Yes I per 2 recorders Corn load IIon-t [ Yes Yes Conforms to l16 reenval 1811 ell) 400*r train UPS Reg Guide heat exchanger f.gT, Rev 2 discharge toepara ttere i
RIsIt flow 0 to 6000 D2 Yes Yes I per 2 meters Complete IE Yes Yes Conforms to Reg, Guide geI/ min train y
s.
. R.
2 Rest valve open/
D2 Yes Yes a per i pair nr Complete er Yes Yes (d) i y
status closed valve lights per l g waeve I"#
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TABLE 7.5.2-1 (SHEET 8A OF 11)
[iv)6ron-t pal 1 Qgp_tig t 80 amber or Impleertn-Power (Cf ISC 8tange/
Iype/
I n s t res.
Coestral Room tateon 500-Indica-Indica-Variab3 hyg Gajp3ng _ mental
}e_lje_ig _ments leut l cn Ll_on_
J_le_
311,,,
Dp tien (giformance Decentseina-1st*3 to
[3 Ito 10 o I per Comesenica tion Complete leon-lE Yes Yes (el teen station 108 er/h plant console diesel-(large paths) backed Deconteelna-10 3 to E3 Ito 10 0 I por Coastenien t iers Complete feon-l[ Yes Yet (el 3
tisws stalleen 304 er/h plant console dieses-(small paths) backed Instrument de-104 to E3 10n Ito i per Coseisnication Complete llon-SE Yes Yes (el contamination 304 er/h plant consoler diesel-station backed Yqoo useED s
O 4
8 DI I
4 e
e
. o D D
.G.E W N m
H
& N
\\ G3
. a> a l#1
1 Insert A to Table 7.5.2-1 Qualif1*atian Implemen-EOF TSC Type /
Environ-Nasuber of Control Room tation Power Indi-Indi-triable Range / Status-Category mental Seismic Instruments Indication Date Supply cation cation Conformance Accident Sampling Capability Primary Coolant Grab Sample E3 NO NO 1 per unit Complete Non-1E Conforms to Reg and Sump Guide 1.97. Rev. 2 o Gross Activity 10pC1/m1 to 10C1/ml NO NO YES o Gamma Spectrtsu Isotopic Analysis NO NO YES.
o Boron Content 0 to 6000 ppm YES (4)
YES YES o Chloride Content 0 to 20 ppm YES (4)
YES YES o Dissolved Hydrogen 0 to 2000 YES (4)
YES YES in primary coolant CC(STP)/Kg 0 Dissolved Oxygen 0 to 20 ppm YES (4)
YES YES in primary coolant 0 pH 1 to 13 YES (4)
YES YES Containment Air Grab Sample E3 NO NO 1 per unit Complete Non-1E Conforms to Res Guide 1.97, Rev. 2 0 Hydrogen Content 0 to 10%
YES (4)
YES YES o Oxygen Content 0 to 384 YES (4)
YES YES o Genua Spectrum Isotopic Analysis NO NO YES High level radio-O to 100%
D3 NO NO 1 per tank Nigh level Complete Non-1E NO NO (r) active liquid tank of span alarm Ir. val R dioactive Gas 0-150 psis D3 NO NO 1 per tank Nigh pres-Complete Non-1E NO NO (s)
Holdup Tank pressure sure alarm 2889t 5
p TABLE 7.5.2-1 (SHEET 9 OF 11)
TA8tt F.5.7-t (seettr g or st)
Gnaa I i r ice t iWL.,
Ikuuber er Iapiemen-Power E0r TSC flange /
Type /
Env6ren-Ins t res-Control Room tation Seap-Indica. Indica-Yar4 agLf Alg1923 fa_tggen _ egg 1pL if Egi el_c _ ment _L JnglICa(lptt,
__ pats _ a 1,y_,_
tien MC Confg r1mppace l
IIeteereIogIcai 10 4 E3 Ile IIe 15 4 mA Coopiete lIA IIA 10 4 Conterims te parameters Itog coside I.gF,_ llev 2 Caa sin =ent m
ts me me u
a Complete a
na na p1 (il l16 redsetlen coat *8a= eat atmospheric (r) toeperettere Contaisenoset teamp esoter ggg tempera tesre
~'
IIent removal by the con-(h) g tainment ran hosL removei O
e,s t-7
-ta i-t seamp. contaln-(i) g ment steos.
phere, and primary g
coolant q
saap t isig Seric acid charging Flow gjg ACS entended rangh pressaere th)
Accesses ta ter (m) tenh level D
.O.
N 0%
e 5
\\co ele a
TW:LE 7.5.2-1 (SHEET 11 OF 11) 1 J
rsaw was not designated a key variable. If the operator uses the SAT for boration following an accident, normal charging riow and reactor coolant system ( ACS) saapilog is used to demonstrate that the ItCS is being borated.
k.
RCS Extended llange pressure 4 BCS wide-range pressiere will be used, l..
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Reactor coolant systee pressure indication and valve position Indication for the accumulator discharge isoletion as4 accismulator vent valves provide adegasete status er the accuotelators, n.
The environment /teeperature for the diesel generator bestiding is monitored by Instrumentation that is designed rer a elld environment, nonselselc, and powered free a non-Class IE Uf*S.
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l lease devices are backasp verification to quellfled system status parameters. These devices are purchased to perfore in their l
antiticipated service environments for the plant conditions for which they must raenction.
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the alternate (sancillaryl power supply will be either battery-backed or powered by the diesel generator.
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4 INSERT B TO TABLE 7.5.2-1 (q) These parameters may be displayed on the emergency response facility computer CRT display in the control room.
(r) The liquid radwaste system is not required following an event. The containment normal sumps and the reactor coolant drain tank discharge lines are isolated by a containment isolation signal. These lines will be isolated subsequent to any LOCA. ECCS pumps are located in flood retaining rooms that prevent the spread of post-LOCA recircu-lation fluid if a pump were to fail. The recycle holdup tank level is-alarmed (at 957. volume) in the control room as part of the liquid radwaste system trouble alarm. An operator would be dispatched to the local control panel to clear the annunciated signal.
(s) The design pressure of each of the waste gas decay tanks (WGDTs) is 150 psig. There are seven WGDTs per unit and two shared shutdown decay tanks. Each tank is provided with a pressure transmitter and a I
high pressure alarm in the control room as part of the gaseous waste processing system trouble alarm. An operator would be dispatched to the local control panel to clear the annunciated signal. The alarms for the WGDTs are set at 100 psig. All of the WGDTs are provided with relief valves set at or below the tanks design pressure.
The relief valves for the WGDTs discharge to the shutdown decay tanks which are normally at low pressure. Should an extended discharge to the shutdown decay tank occur a high alarm would be received prior to lifting of the shutdown decay tank relief valve.
The relief valves for the shutdown decay tanks discharge to the plant vent which is monitored by the plant vent monitor.
Failure of one of these tanks has analyzed in subsection 15.7.1.
Based upon the protection afforded by the installed tank relief valves and the potential eventual release to the plant vent, the gaseous waste processing system trouble alarm in the control room is adequate to provide information concerning the status of the WGDTs.
(t) The containment effluent radioactivity is monitored by the plant vent monitor. The plant vent receives the discharges from the containment purge system, auxiliary building, control building, and the fuel handling building.
(u) Accumulator isolation valve status is a part of the ECCS valve status.
j (v) Emergency ventilation damper position is a part of the heating, ventilation, and air conditioning system status.
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I 2738t-1
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