Text

Forwards marked-up Second Draft of Facility Tech Specs.Util Should Be Instructed to Carefully Review Second Draft & Develop List of Issues to Resolve.Critical Concerns & List of Missing Info to Tech Specs Encl
	ML20132C788
Person / Time
Site:	River Bend
Issue date:	03/08/1985
From:	Crutchfield D; Office of Nuclear Reactor Regulation
To:	Novak T; Office of Nuclear Reactor Regulation
Shared Package
ML20132C450	List: IR 05000458/1985035; ML20132C446; ML20132C788; ML20132C814; ML20132C933; ML20132C945; ML20132C982; ML20132C991; ML20132D021; ML20134P251; ML20134P294; ML20134P304; ML20134P354; ML20134P367; ML20134P386;
References
	FOIA-85-511 NUDOCS 8503180532
	Download: ML20132C788 (48)
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,/ '*I,k UNITED STATES NUCLEAR REGULATORY COMMISSION j

j WASHINGTON, D. C. 20555 8

s,..... /

March 8, 1985 i

MEMORANDUM FOR: Thomas M. Novak, Assistant Director for Licensing Division of Licensing FROM:

Dennis M. Crutchfield, Assistant Director for Safety Assessment Division of Licensing

SUBJECT:

RIVER BEND TECHNICAL SPECIFICATIONS - SECOND DRAFT

~

m.

The Second Draf t of River Bend Technical Specifications has been prepared and is anticipated to be finished through CRESS on or about March 11, 1985.

A. complete printed copy of the Draft will be provided to Steve Stern, PM to formally transmit to Gulf States Utilities at that tim

',na rk-up Draft (identical to that provided to CRESS) was given to u n Price (GSU) on February 25, 1985 so that the utility could begin their review. A copy of their informal coments on this Draft is attached (Enclosure 1). Many of these comrients are sketchy and require additional information. The utility has been requested to supply mark-up TS pages as well as discussion and justification for the proposed changes.

In regard to Enclosure 1, the utility has characterized their coments as (1) critical, needed for low power licensing and fuel load, and (2) the remainder to be resolved af ter licensing. We have informed them that such an approach is unacceptable because it is inconsistent with our current policy of requiring complete Technical Specifications at the low power licensing stage.

In order to facilitate our preparation of the Proof and Review Draft for the Technical staff review, the utility should be instructed to carefully review the Second Draft and develop a list of issues to resolve.

In the past, the justification for changes or deletions to the document has been rather meager and in numerous instances, contrary to the description in their FSAR. Whenever the applicant is proposing a deviation.from the STS based on a River Bend design difference they must provide complete in-fonnation including specific design details to justify the deviation. This will require that they apply substantial resources in an organized manner to do a quality review, particularly at this stage.

In addition to the above review, the utility still has not provided the information described in Enclosure 2.

The utility was provided a copy of this on February 25, 1985. All of this material is needed to provide a complete Proof and Review Draft.

CONTACT:

DHouston 28933 T

N n _2l

Thomas M. Novak March 8, 1985 4

Upon receipt of the above requested information and further resolution of their concents, we will prepare the Proof and Review copy for ipternal review lIennisM.

1' utch feld, ssistant Director for Safety Assessmen Divison of Licensing l

Enclosures:

1.

Critical Concerns 2.

List Missing Information to River Bend TSs I

1 1

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Q%fk INSERT PRIMARY CONTAlhMENT 1hTEGRITY - SHlTTDOhN a

1.32 PRIMARY CONTAIhMEhT 1hTEGR17Y - SHlTTD0hN shall exist khen:

a) All containment penetrations required to be closed during accident conditions are either:

1) Capable of being closed by an OPERABLE containment auto-matic isolation system, or

2) Closed by at least one manual valve, blind flange, or de-activated automatic valve secured in its closed position l

I except as provided in Specification 3.6.4.

b) All containment hatches are closed.

c) At least one door in each air lock is closed.

O

INSERT SECONDARY CONTAINMENT INTEGRITY - FUEL BUILDING 1.39 SECONDARY COSTAINMEhT 1hTEGRITY - FUEL BUILDING shall exist when:

a) All Fuel Building penetrations required to be closed during accident conditions are closed by valves, blind flanges, or da=pers secured in position.

b) All Fuel Building equipment hatch covers are installed.

l c) The Fuel Building Charcole Filtration System is in compliance with the requirements of Specification 3.6.6.5.

e) At least one door in each access to the Fuel Building is closed, except for routine entry and exit of personnel and equipment, f) The pressure within the Fuel. Building is maintained in compliance with the requirements of Specification 4.6.5.1.2.a.

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$f"'s 3 C S F.kT

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l TURBINE BYPASS SYSTEM RESPONSE TIME 1.44 The TURRINF. BYPASS SYSTEM RESPONSE TIME consista of two components:

a) time from initial movement of the main turbine stop valve or control valve ubtil 80%

of turbine bypass capacity is established, and b) the time from initial movement of the usin turbine stop valve or control valve until initial movement of the turbine bypass valve.

The response times may be measured by Sny series of sequential, overlapping or total steps puch that both entire response time components are seasured.

6 9

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1 3/4_.1__ REACTIVITY CONTROL SYSTEMS 3/4 1 1 5HUTDOWN MARGIN LIMITING CONDITION FOR OPERA 110N 3.1.1 The SHUTDOWN MARGIN shall be equal to or greater than:

0.38% delta k/k with the highest worth rod analytically determined, or a.

b.

0.28% delta k/k with the highest worth rod determined by test.

APPLICABILITY: OPERATIONAL COND]TIONS 1, 2, 3, 4 and 5.

ACTION:

With the SHUTDOWN MARGIN less than specifie~d:

In OPERATIONAL CONDITION 1 or 2, reestablish the required SHUTDOWN a.

MARGIN within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-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 .

In OPERATIONAL CONDITION 3 or 4, isusediately verify all insertable b.

control rods to be inserted and suspend all activities that could reduce the SHUTDOWN MARGIN.

In OPERATIONAL CONDITION 4, establish H69N9MW CONTAIMENT INTEGRITY within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months .

PRm m L.5HUTOOWN In OPERATIONAL CONDITION 5, suspend CORE ALTERATIONS # and other activ-c.

ities that could reduce the SHUTDOWN MARGIN and insert all insertable

~

control rods within I hour. Establish OC;;;J,c.m. CONTAINMENT INTEGRllY-$HLfDh!

- within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months .

PRMAW SURVEILLANCE REQUIREMENTS 4.1.1 The SHUTDOWN MARG]N shall be determined to be equal to or greater than specified at any time during the fuel cycle:

By measurement, prior to or during the first startup after each a.

refueling.

b.

By measurement, within 500 WD/T prior to the core average exposure at which the predicted SHUTDOWN MARGIN, including uncertainties and calculation biases, is equal to the specified limit.

Within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after detection of a withdrawn control rod that is c.

immovable, as a result of excessive friction or mechanical inter-ference, or is untrippable, except that the above required SNUTDOWN MARGIN shall be verified acceptable with an increased allowance for the withdrawn worth of the immovable or untrippable contr' l rod.

e FL 7,

...,,,,.: ; r.,, T.,

.,.,..:. _... :. J. ;.. ;. -

RIVER BEND - UNIT 1 3/4 1-1

_ TABLE 3.3.2-1 g

ISOLATION ACTUATION INSTRUNENTATION

. VALVE GROUPS NINIMlM APPLICA8tE E

OPERATED BY OPERABLE CHANNELS OPERATIONAL TRIP FUNCTION SIGNAL *** PER TRIP _ SYSTEM (a)

_ CONDITION ACTION g

1.

PRIMARY CONTAIMMENT ISOLATION

~*

a.

Reactor Vessel Water Level-Lo$ow,Leve) 2 1, 7, 8, 9(b)M 2

1,2,3end4.

20

(

b.

Drywell Pressure - High 1,3,8(b)(c)(k) 2 1,2,3 20 c.

Containment Purge 8

1 1,2,3and*/

21 Isolation Radiation -

(

High d.

Manual Initiation 1,3,7,8 2/ group 1, 2, 3 M 22

(

{

2.

MAIN STEAM LINE ISOLATION w

a.

Reactor Vessel Water Level-Low Low Low, Level 1 6(c) 2 1,2,3 20 w

b.

Main Steam Line Radiation - High 6,9(d) 2 1,2,3 23 c.

Main Steam Line Pressure - Low 6

2 1

24 d.

Main Steam Line I

2/ g ')

Flow - High 6

1, 2, 3 23 e.

Condenser Vacuum - Low 6

2 1, 2**, 3**

23 f.

Main Steam Line Tunnel Temperature - High 6

2 1,2,3

23... -

e g.

M5fn Steam Line Tunnel a Temperature - High 6

2 1,2,3 23 h.

Main Steam &&me Leses Area Temperature -

High (Turbine Butiding) 6 2 /etta 1, 2, 3 23 1.

Manual Initiation 6

2/ group 1, 2, 3 22

_ TABLE 3.3.2-1 (Continued)

ISOLATION ACTUATION INSTRUMENTATION VALVE GROUPS MININUM APPLICABLE OPERATED BY OPERABLE CHANNELS OPERATIONAL TRIP FUNCTION SIGNAt*** PER TRIP SYSTEM (a)

_ CONDITION ACTION 3.

SECONDARY CONTAINNENT ISOLATION o

a.

Reactor Vessel Water Level-Low Low, level 2 11, 12, 2

1, 2, 3 endJ 25 13(b)(f)(1)(j) b.

Drywell Pressure - High 11, 12, 2

1,2,3 25 13IDIIC)IIII')III IIIIII c.

Fuel "--fn; " x 13 2

1,2,3. W 28 Building ventilation E

Exhaust Radiation - High Y

d.

Reactor Building 12(b)(f)(j) 1 1, 2, 3. emba 79 2

Annvius Ventilation Exhaust Radiation - High Q ^... C.: ] :.y ^ ;. y.

. ^. ^

^ ' " " "

^^

.:.::p g

~

t #'

Manual Initiation 11, 12, 13 1/ group 1, 2, 3 26 4.

REACTOR WATER CLEANUP SYSTEN ISOLATION a.

A Flow - High 7

1 1,2,3 27

~"

b.

a' Flow Timer 7

1 1,2,3 27 c.

Equipment Area Temperature - 7 1

1,2,3 27 High d.

Equipment Area a Temp. -

High 7

1 1,2,3 27 e.

Reactor Vessel Water Level - Low Low, Level 2 7

2 1,2,3 27 f.

Main Steam Line Tunnel 7

1 1, 2, 3 27 Ambient Temperature - High

l -.

TABLE 3.3.2-1 (Continued)

ISOLATION ACIUAT]ON INSTRUMENTATION AC110N ACTION 20 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 SHUT 00=%

within the next 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

ACTION 21 Close the affected system isolation valve (s) within one hour or, In OPERATIONAL CONDITION 1, 2, or 3, be in at least HOT a.

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 .

b.

In Operational Conditione, suspend CORE ALTERATIONS, handling of irradiated fuel in the primary containment and operations with a potential for draining the reactor vessel.

ACTION 22 Restore the manual initiation function to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 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 .

ACTION 23 Se in at least STARTUP with the associated isolation valves closed within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months or 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 .

ACTION 24 Be in at least STARTUP within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

eMRAft se&

ACTION 25 Establish SECONDARY CONTAINHENT INTEGRITY with the standby gas treatment system operating within one hou,r.

ACTION 26 Restore the manual initiation function 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 NOT SHtfTDOWN 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 .

ACTION 27 Close the affected system isolation valves within one hour and declare the affected system inoperable.

ACTION 28

...J,.. ::: ^:;ti ::^:~ ^ ::Z:::' : ~::::'". ; ^ 1_ :^- t ;--

0 x^__.". ;;._: c,

^J.

t_.

Initiate and maintain the 1

Fuel Building ventilation System in the Filtration mode of i

1 operation.'^., C !.:-..

a astueW 1 soevn.

ACTION 29 5: t:$ ;! 0 0:00'*" 00":"" ' !::::'" : ^_t t!. ; ; ^.. ~.,,..

1 ::t : ^_ :;: :^' ; M it'

-: t-.

Initiate and maintain annulus mixing system with the reactor building annulus exhaust to at least one operating standby gas treatment train within

'i'nus; ACTION 30 Lock the affected system isolation valves closed within one hour and declare the affected system inoperable.

RIVER BEND - UNIT 1 3/4 3-18

TABLE 3.3.2-1 (Continued)

ISOLATION ACTUATION INSTRUMENTATION ACTION 9

NOTES When handling irradiated fuel in the containment and during CORE ALTERATIONS and operations with a potential for draining the reactor vessel.

May be bypassea with reactor steam pressure ( 1043 psig and all turbine stop valves '... ^i_. ?N _;_ ; 2

__2_. t : :1 ':' " "T'e so sara The valve groups listed are designated in, Tables 3.6.4-1 and 3.6.5.2-1.

I ' _' EY_~'T:

~'TT'~'"''''~'~'~'"'

' -' ~ ~'

(a) AchanneI'may~beplacedinaninoperablestatusforupto2hoursfor

~

required surveillance without placing the trip system in the tripped condition provided at least one other CPERABLE channel in the same trip system is monitoring that parameter.

(b) Also actuates the standt,y gas treatment system.

(c) Also actuates the main control room air conditioning system in the emergency

~

node of operation.

(d) Also trips and isolates the air removal pumps.

(e)

(f) Also actuates secondary containment ventilation isolation dampers e=#-

T:'..- per Table 3.6.5.2.1.

(g) Manual initiation of SLCS pump C @g closes G33-F001, and eave 4 'nitiation o

of StC5 pump C001A closes G33-F004.

(h) Requires RCIC system steam s@ ply pressure-low coincident with drywell pressure-high.

(1) A1}o starts the Fuel Building Exhaust Filter Trains A and B.

(j) Also starts the Annulus Mixing System.

(k) Also actuates the containment hydrogen analyzer /sonitor recorder.

m RIVER BEND - UNIT 1 3/4 3-19

...---s p

.--,.,.c-

l V

l 5

l l

_ TABLE 4.3.2.1-1 h

ISOLATION ACTUATION INSTRUMFNTATION SURVEILLANCE REQUIREMENTS m

CHANNEL 5

OPERATIONAL CHANNEL FUNCTIONAL CHANNEL CON 0!TIONS IN WHICH TRIP FUNCTION

_ CHECK TEST CALIBRATION SURVEILLANCE REQUIRED 1.

PRIMRY CONTAINMENT ISOLATION w

a.

Reactor Vessel Water Level -

Low Low, level 2 5

M R (84 1, 2, 3 andd.

b.

Drywell Pressure - High 5

M R (CI 1, 2, 3 c.

Containment Purge Isolation Radiation - High 5

M R

1, 2, 3 and e

d.

Manual Initiation NA I

M *)

NA 1, 2, 3 and=e.

l 1

w1 2.

M41N STEAM LINE ISOLATION Y

a.

Reactor Vessel Water Level -

M Low Low Low Level 1 5

M R "I I

1, 2, 3

)

b.

Mein Steam Line Radiation -

High 5

M R

1,2,3 c.

Main Steam Line Pressure -

Low S

M R I8I 1

d.

Main Stese Line Flow - High S

M R IO 1,2,3 e.

Condenser Vacuum - Low S

M R I8%

f.

Main Steam Line Tunnel 1, 2**, 3**

Temperature - High 5

M R

g.

Mafn Steam Line Tunnel 1,2,3

~"'

a Temp. - High S

M R

1, 2, 3 a,

h.

Main Steam Line Area S

M R

1, 2, 3 l

Temperature-HIgh 1

(Turbine Building) 1.

Manual Initiation NA M(a)

MA 1, 2, 3 i

_ TABLE 4.3.2.1-1 (Continued) 7 m

[

ISOLATION ACitlATION INSTRUNENTATION SWVEILLANCE REQUIREMENTS y

o e

CHANNEL OPERATIONAL

[

CHANNEL FUNCTION 4L CHANNEL CONDITIONS IN WHICH

[

TRIP FUNCTION

_ CHECK

. TEST

, CALIBRATION SURVEILLANCE REQUIRED 3.

SECONDARY CONTAlf84ENT ISOLATION a.

Reactor vessel Water Level - Low Low, Level 2 5

M R 'I 1, 2, 3 W I

b.

Drywell Pressure - High 5

M R ("I 1, 2, 3 i

c.

Fuel Bufiding enes Ventilation

{

Exhaust Radf ation - High Megh 5 M

R 1, 2, 3 se y

d.

Reactor Building Annulus Ventilation 0

Exhaust Radiation - High @ 5 M

R 1, 2, 3 W

": ::^ ; - " ? !", ".. _ L.

y wwwww w

--wwy v

ga WM

~ ? n " n-M *I I

(#.

Menval Intt1ation MA MA 1, 2, 3 ene*

4.

REACTOR W TER CLEANUP SYSTEM ISOLATION a.

A Flow - Hfgh 5

M R (CI 1, 2, 3 b.

A F. low Timer NA M

Q 1, 2, 3 -- - -

'c.

Equipment Area Te nerature -

High 5

M R

1, 2, 3 d.

Equfpoent Area Wea E&eeden a Temp.

HIgh 5

M R

1, 2. 3 1

m 3

TABLE 4.3.2.1-1 (Continued) m ISOLATION ACTUATION INSTRUNENTATION SURVEILLANCE REQUIREMENTS s.

g CHANNEL OPERATIONAL CHANNEL FUNCTIONAL CHANNEL CONDITIONS IN WHICH E

TRIP FUNCTION CHECK TEST CALIBRATION SURVEILLANCE REQUIRE 0 6.

RHR SYSTEM ISOLATION (continued) w c #.

Reactor vessel Water Level -

R.M Low, level 3 M

1,2,3 Ja.

Reactor Vessel Water Level -

Low Low Low, level 1 5

M R

1, 2, 3 8 #.

Reactor Vessel (RNR Cut-in Permissive) Pressure - High 5

M R M 1, 2, 3 f q.

Drywe11 Pressure - High 5

M(,)

R M 1, 2, 3 3 Jr.

Manual Initiation MA M

MA 1, 2, 3 Y.

estesTom Sfames Paestants 3 lost 3 PSeis emJ[er Y

Whenhandlingh)radiatedfuelinthe.._-.^_.,

3 inment and during CORE ALTERATIONS and operations with a potentia _

for draining the reactor vesse.

PA'"'*

V

- When tL - :::::: " t fr'"? ^ '- T - ' any turbine stop valve ': ;. _;t;. ^^ _.. C open.

E _ _ I __ _ _ T.

17 7. "C ^,^.^ _.. _^ _ _... I.... ^. ^ ^.

. t i. t I _ I 7 ;. f.. I. '., " ^..... _ "....

,J I

^

i (a)[Manua initiation switches shall be tested at least once per 18 months durina shutdown 3 All e4her circu'try associated with manual initiatto hall receive a CHANNEL FUNCil0NAl Il$i at[least once per 31 days as part of circuitry required t be tested for automatic system isolation.9 (b) Each train or logic channel shall be testedj t least every other 31 days.

E oftese venees sneestee, esserteresee $4petteset i

(d Cas.soceve T aen u wer save.e er av s. seer owca Pam 31 oavs.

8

5 TABLE 4.3.4.2.1-1 END-0F-CYCLE RECIRCULATION PUNP TRIP SYSTEM SURVEILLANCE REQUIREMENTS m

E CHANNEL 5

TRIP FUNCTION FUNCTIONAL CHANNEL TEST CALIRRATION 1.

Turbine Stop Valve-Closure MF #

R#

2.

Tudine Control Valve-Fest Closure M##

R T..;:., -'. ^. :-

=

m

==

R Y

C..,.; a :.., ^. :,.,.'

:. ^_.:..

E

; :1. _ ^ ; ^ -

0

_.. ^. ;^. :: _; ^. :.;_ ;;.

0". f_,_.

7 The CNAsuIptL FONcreewAL e.A CH4Nett.L CAlt9f AfsOM skall shelvde 4velre'ne i

rmsr 36 9e ems es #wsvreme=4s.

e C

i

g\\M\\

INSTRUMENTATION RAD 10ACTlvE LIQUID EFFLUENT MONITORING INSTRUMENTATION j

s LIMITING CONDITION FOR OPERATION

^

3.3.7.10 The radioactive liquid effluent monitoring instrumentation channels shown in Table 3.3.7.10-1 shall be OPERABLE with their alarm / trip setpoints set to ensure that the limits of Specification 3.11.1.1 are not exceeded. The alare/ trip setpoints of these channels shall be determined and adjusted in accordance with the methodology and parameters in the OFFSITE DOSE CALCULATION MANUAL (0DCM).

APPLICABILITY: At all times.

ACTION:

a.

With a radioactive liquid effluent monitoring instrumentation channel h trip setpoint less conservative than required by the above Specification, immediately suspend the release of radioactive liquid ef fluents monitored by the affected channel, or declare the channel inoperable.

C #.

With less than the minimum number of radi6 active liquid effluent monitoring instrumentation channels OPERABLE, take the ACTION shown in Table' 3.3.7.10-1.

Restore the inoperable instrumentation to OPERABLE status within the time specified in ACTION or explain in the next Semiannual Radioactive Effluent Release Report why this inoperability was not corrected within the time specified.

ds' The provisions of Specifications 3.0.3 L. 0. 4, M " ^ 1 ^ t a re 3

f not applicable.

eend SURVEILLhNCEREQUIREMENTS 4.3.7.10 Each radioactive liquid effluent monitoring instrumentation channel shall be demonstrated OPERABLE by performance of the CHANNEL CHECK, SOURCE CHECK, CHANNEL CALIBRATION and CHANNEL FUNCTIONAL TEST operations at the frequencies shown in Table 4.3.7.10-1.

Waru a re ~..mavive s.. arnusar moverenews swe 2;

ew.an.

mer nre..ur s.en s.unevneeve v=.. nr rsumswr virse or vesa oe.ve specirer reem,arrauswr rueous was vwn estuwer

)i em*v **= ve n us pneveere fut CHANNE,L CH ECK resowency reevired by Speceserev,.u 44.3.7. Io en ea.cre.aa, v. wem k

ran 12. Howrs.

RIVER BEND - UNIT I 3/4 3-94

B

<0 TABLE 3.3.7.10-1 RA010 ACTIVE. LIQUID EFFLUENT MONITORING INSTRUMENTATION MINIMUM CHANNELS INSTRUMENT OPERABLE ACTION 1.

Gross Radioactivity Monitors Providing Alarm and Automatic Termination of Release a.

LiquidRedwesteEffluentLine(%RMS-RE107) 1 100 2.

Gross Radioactivity Monitors Providing Alarm but not Providing Automatic Termination of Release CoolIngTower81owdownLine(%RMS-RE108) 1 101

$f a.

e*

3.

Flow Rete Pleasurement Devices a.

LiquidRadwesteEffluentLine(%tWS-FE197) 1 102 b.

Cooling Tower Slowdown Line (kWS-FE113) 1 102 OW t

l 1

]

l l

l TABLE 3.3.7.10-1 (Continued)

I TABLE NOTATION ACTION 100 -

With the number of channels CPERABLE less than required by the Minis m Channels OPERABLE requirement, effluent releases may continue a release:

provided that prior to initiating At least two independent samples are analyzed in accordance a.

with Specification 4.11.1.1.1 and i' ?? ? 1.?, -- O b.

At least two technically qualified memebers of the facility staff independently verify the release rate calculations and discharge line valving; Otherwise, suspend release of radioactive effluents via this pathway.

ACTION 101 -

With the number of channels 0PERABLE less than required by the Minism Channels OPERABLE requirements, effluent releases via this pathway may continue "

, _ :: 2;g provided that, at

^

least once per (12) hours, grab samples are c;ollected and an (for gross radioactivity (beta or gassa) at a limit of detection of at least 10 7 microcuries/al).

ACTION 102 -

With the number of channels OPERABLE less than required by the Minis m Channels OPERABLE requirement, effluent releases via this pathway may continued . y

^_: _, ;; provided the flow

. rate is estimated at least once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months during actual releases.

Pump curves generated in situ may be used to estimate flow.

.~

RIVER BEND - UNIT 1

't/* *-*c

5

5 TABLE 4.3.7.10-1 m

RADI0 ACTIVE LIQUID EFFLUElfT MONITORING INSTRUMENTATION SURVEILLANCE REQ g

CHANNEL

~

CHANNEL SOURCE CHANNEL FUNCTIONAt.

]

INSTRUMENT

__ CHECK e

_ CHECK CALIBRATION TEST 1.

Gross Radioactivity Monitors Providing Alarm and Automatic Termination of Release a.

Liquid Redweste Effluent Line (NIMS-RE107)

D P

4AHt($

Q(1) 2.

Gross Radioactivity Monitors Providing Alam but not Providing Automatic w1 Termination of Release a.

Cooling Tower Blowdown Line (WIMS-RE108)

D M

R(3)

Q(2) 3.

Flow Rate Measurement Devices j

a.

Liquid Radweste Effluent Line l

(RLWS-FE197)

O(4)

N.A.

R Q

i b.

Cooling Tower Blowdown Line (ECWS-FE113)

O(4)

N.A.

R Q

TABLE 4.3.7.10-1 (Continued)

TABLE NOTATION (1) The CHANNEL FUNCTIONAL TEST shall also demonstrate that automatic isolation of this pathway - ' :- *- ' :-

2':

- _.._^...- occur if any of the following conditions exists

1.

Instrument indicates measured levels above the alars/ trip setpoint.

2.

Circuit failure.

,__._ _-_. 1_ge 7-i.

. ; ^.. -

.. ;_.l.;I; n;t ;;t ' ;;; ;;; ;;;,

^

(2) The CHANNEL FUNCTIONAL TEST shall also demonstrate that control room alarm annuciation occurs if any of the following conditions exists:

1.

Instrument indicates measured levels above the alara setpoint.

2.

Circuit failure.

O.

...^. _.

'.4:..^..,. :_c.;.;'; f;

C.

:.. ^.. _ ; :. ". ;. ^. e '.. :.. "... ".

^_;

;.

(3) The initial CMANNEL CALIBRATION shall be performed using one or more of the reference standards certified by the National Bureau of Standards or using standards that have been obtained from suppliers that participate i

in measurement assurance activities with N85. These standards shall permit calibrating the system over its intended range of energy and measurement range. For subsequent CHANNEL CALIBRATION, sources that have been related to the initial calibration shall be used.

^

' ^ --

' ^'^ ^-

'

: '; ::" :t' ':'; ::ir;'_i;n ;:::: _:;. ?;. ^2.:. ::;_'---- ' !

(4) CHANNEL CHECK shall consist of verifying indication of flow during periods of release. CHANNEL CHECK shall be made at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months on days which continuous, periodic, or batch releases are made.

RIVER SEND - UNIT 1 3/4 3-98

l INSTRUMENTATION RADIDACTIVE GASEOUS EFFLUENT SONITORING INSTRUMENTATION LIMIT]NG CONDITION FOR OPERATION I

3.3.7.11 The radioactive gaseous effluent monitoring instrumentation channels shown in Table 3.3.7.11-1 shall t>e OPERABLE with their alarm / trip" setpoints set to ensure that the Ifmits of Specification 3.11.2.1 are not exceeded. The alare/ trip setpoints of these channels shall t>e determined and adjusted in accordance with the methodology and parameters in the ODCM.

i APPLICABILITY: As shown in Table 3.3.7.11-1.

ACTION:

With a radioactive gaseous effluent monitoring instrumentation channel a.

e& sam / trip

setpoint less conservative than required by the above Specification, immediately suspend the release of radioactive gaseous effluents monitored by the affected channel, or declare the channel inoperable.

C X.

With less than the minimum number of radioactive gaseous 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 in the next Sealannual Radioactive Effluent Release Report why this inoperability was not corrected within the time specified.

ds.

The provisions of Specifications 3.0.3,3.0.4, Q 4,eid.eie are not f

applicable.

SUREVEILLANCE REQUIREMENTS 4.3.7.11 Each radioactive gaseous effluent monitoring instrumentation channel shall tre demonstrated OPERABLE by performarce of the CHANNEL CHECK, SOURCE CHECK, CHANNEL CALIBRATION and CHANNEL FUNCTIONAL TEST operations at the frequencies shown in Table 4.3.7.11-1.

84The alara/ trip setpoints for the Explosive Gas Mixture in the Main Condenser Of fgas Treatment System, and the Main Condenser Offgas Treatment Noble Gas i

Activity Monitor are set in accordance with Specification 3.11.2.6 and

3.11.2.7. respectively.i i

(b.LJsvua. rest.'.o4.*we seseous erewsur se.m.oua keserveasar a) ce4 easel suces ser,eewr a,en causerva,rews tweaa aamuesto

& TNa snows spee,,,c.w.w, gerwwww res.e.ss e e,, vwas I

Femassy sn, eenvsw,e pne,ssee resa C NA N MEL-CHE68C

(

Favaveu s.v asewsto or Sessesisar.c>w 4.3.7, gl,, ew r,. e d TD ##C# Per BR Newes.

RIVER BEND - UNIT 1 3/4 3-99 l

g TABLE 3.3.7.11-1

=

g RADI0 ACTIVE G45E00$ EFFLUENT MONITORING INSTRUMENTATION 5

I MINIMUM CHANNELS U

INSTRtMENT OPERA 8tE APPLICA81t!TY ACTION w

~

,,K-_~.

1- __,-_.__

- : *: "_^ _'^

^^

^

l Te est M.1

'". _ _ : f' ; - ? _. _ ;- : ^^_______:

i

.. _ :.. ^. : _. -,, " i ? ; _,, 7 Irem J

???

4 le.

Main Condenser Offgas Treatment System T

Emplosive Gas Monitoring System (for systems designed to withstand the

{

effects of a hydrogen explosion) a.

", ^ ; ;;..

(downstress of the recombiner) 1 125 th:

Main Plant Exhaust Doct Monitoring System a.

Noble Gas Activity Monitor 1

123 b.

Iodfne Sampfer 1

127 c.

Particulate Sampler 1

127 C

d.

Effluent system Flow Rate Montter 1

122 4

e.

Sampler Flow Rate Monitor 1

122 t

=q E

TABLE 3.3.7.11-1 (Continued) 5 RADIDACTIVE GASEOUS EFFLUENT MONITORING INSTRUMENTATION g

(

INSTRUMENT MININUM CHANNELS OPERABLE APPLICABILITY ACTION 3A' Fuel Building Exhaust Duct Monitoring System Noble Gas Activity Monftor a.

1 b.

Iodine Sampler 123 1

127 c.

Particulate Sampler Y

1 127

^

d.

Flow Rate Monitor 1

122 Sampler Flow Rate Monitor e.

1 122 ale' Redwoste BuIIdIng VentiIstion Exhaust Duct Monitoring System Moble Gas ActIyity Monfter a.

1 i

123 b.

Iodine Sampler 1

C 127

-7 c.

Particulate Saar ter 1

127 d.

Flow Rate Monitor

.-ry 1

122 j

e.

Sampler Flow Rate Monitor 1

122 1

_. :.. _. r :p..

.s

" ~^

',:_.^^

' i f _,.

^ :^~ ;

Ik he W r._

\\

Taut 3.1.1.H

DR\\FT TABLE 3.3.7.11-1 (Continued) f TABLE NOTATION At all times.

During main condenser offgas treatment system operation.

During operation of the main condenser air ejector.

,;T;;,^^-

.'....mi,

^ ; R; ^., ^ L..

.,... ]

....m

..m.

..y....

^^

C;...;.1.^^;"."".{.7...;n...,it; y t:-13

^

....,,, -, n.......

n it.: .

^

(

> Due & Ma**

s.

w_....,

.E' 7;---

.1: ~ n : ~ :: '

Tffsm &

nm - ;.-- - _ i.-i--

- n,wr --

t i;..., t; '^. ';;;' "CT !?"'0SY JtM - !? i:- _.

a ACTION 122 -

With the number of channels OPERABLE 1ess than required by the Minimum Channels OPERABLE requirement, effluent releases via this pathway may continue provided the flow rate is estimated at least once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

ACTION 123 -

With the number of channels OPERABLE less than required by the Minimum Channels OPERABLE requirement, effluent releases via this pathway say continue provided grab samples are taken at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and these samples are analyzed for gross activity within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

ACTION 125 -

With the number of channels OPERABLE less than required by the Minimum Channels OPERABLE requirement, operation of main condenser offgas treatment system say continu provided grab samples are collected at least once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months and analyzed within the following 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

% 4 T

? "" ;-

ACTION 127 -

With the number of Channels OPERABLE less than required by the Minimum Channels OPERABLE requirement, ef fluent releases via this pathway say continue provided samples are continuously collected with auxiliary sampling equipment as required in Table $pu d l

4.3.7.81-1 i

RIVER BEND - UNIT 1 3/4 3-102

2<

E

_ TABLE 4.3.7.11-1 5

RADI0 ACTIVE GASEOUS EFFLUENT MONITORING INSTRUMENTATION SURVEILLANCE REQUIR c5 CHANNEL MODES IN WHICH CHANNEL SOURCE CHANNEL FUNCTIONAL SURVEILLANCE

[

INSTRUMENT CHECK' CHECK

' CALIBRATION TEST REQUIRED

. _ _ _ _ _ _. ~..,... _._ _.. ____

-"AY 3'L.

.T T ITLT LT y L WL TV y 4

"_i': ?: _;

^ t',_;"t, -. _.

^

w._

' ;^5. 3 0 '..[

^

20;

^G)

^

2.

MAIN CONDENSER 0FFGAS TREATIENT SYSTEM EXPLOSIVE GAS MDMITORING wO SYSTEM (for systems designed to O

withstand the effects of a hydrogen explosion Hydrogen %998P a.

.-. _. (downstream of the recombiner)

D N. A.

Q(4)

M l

3.

MIN STACK MDNITDRING SYSTEM a.

Noble Gas Activity Moniter D

N R(3)

Q(2) b.

Iodine Sampler W

N.A.

M.A.

i i

c.

Partfculate Sampler W

N.A.

g d.

Effluent System Flow Rate l

Monitor D

N. A.

R Q

e.

Sampler Flow Rate Monitor D

N.A.

R Q

i i

S y

TABLE 4.3.7.11-1 (Continued) s RADIDACTIVE CASEOUS EFFLUENT MONITORING INSTRUMENTATION SURVEILLANCE REQUIRE g

CHANNEL M00ES IN tm!CH CHANNEL SOURCE CHANNEL FUNCTIONAL SURVEILLANCE

]

INSTRlMENT

_ CHECK CHECK CALIBRATION TEST REQUIRED 4

FUEL BUILDING ENHAUST DUCT MONITORING SYSTEM a.

Noble Gas Activity Monttor D

M R(3)

Q(2) b.

Iodine Sampler W

N.A.

w c.

Particulate Sampler W

N.A.

k w

d.

Flow Rate Monitor D

N.A.

R Q

k e.

Sampler Flow Rate Monitor D

N.A.

R Q

5.

RADWASTE BUILDING VENTILATION EMMAUST DUCT MONITORING SYSTEM a.

Noble Gas Activity Monitor D

M R(3)

Q(2) b.

Iodine Sampler W

N.A.

c.

Partfculate Sampler W

N.A.

d.

Flow Rate Monitor D

N.A.

R Q

e.,

Sampler Flow Rate Monttor D

N.A.

R Q

O V.

bw

'L7 L ' J L n M5n L sFL L ILTU

'N & m E 3v3 I T "2 ' "--

- ^ ' ^ "

.:^

-t

_ TABLE 4.3.7.11-1 (Continued)

TABLE NOTATIONS At all times.

During main condenser offgas treatment system operation.

h 0c'n; :;: :t': :' tt: --' ::12:n:::. '. a..^....

(1) The CHANNEL FUNCTIONAL TEST shall also demonstrate that automatic isolation of this pathway and control room alarm annunciation occur if any of the following conditions exists:

1.

Instrument indicates measured levels above the alarm / trip setpoint.

2.

Circuit failure.

0.

:.. ^. _ _.. '-:::. :. _ ::_.:._!. ?_i?_...

^

t

;.. ^.. _... ^. :. ^.. '.. :2 ^... ^.

7.. _..

2-l..

^

(2) The CHANNEL FUNCTIONAL TEST shall also demonstrate that control room alarm annuciation occurs if any of the following conditions exists:

1.

Instrument indicates measured levels above the alara setpoint.

2.

Circuit failure.

2.

In:1-

-t '-d'::t:

f: _: ': 1;i'...

? :1 ----i :: ^ :': -:t :: ' :;;:_t;

f_.

(3) The initial CHANNEL CALIBRATION shall be performed using one or more of the reference standards certified by the National Bureau of Standards or using standards that have been obtained from suppliers that participate in measurement assurance activities with N85. These standards shall permit calibrating the system over its intended range of energy and measurement range. For subsequent CHANNEL CALIBRATION, sources that have been related to the initial calibration shall be used.

(4) The CHANNEL CALIBRATION shall include the use of standard gas samples containing a nominal:

1.

One volume percent hydrogen, balance nitrogen, and 2.

Four volume percent hydrogen, balance nitrogen.

RIVER BEND - UNIT I 3/4 3-105 c._-

l

_INSTRLMENTATION 3/4.3.8 TURB1hE OVERSPEED PROTECTION SYSTEM

'I LIMITING CONDITION FOR OPERATION l

3.3.8 At least one turbine overspeed protection systern shall be OPERABLE.

1 APPLICABILITY: OPERATIONAL CONDITIONS I and 2.

ACTION:

j With one turbine control valve, one turbine throttle stop valve or a.

one turbine reheat stop valve per high pressure turbine steam lead inoperable and/or with one turbine interceptor valve per low turbine steam lead inoperable, restore the inoperable valve (s) to pressure E

I OPER.ABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or close at least one valve in the autTN affected steam lead or isolate the turbine from the steam supply within #

the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

gg 0A b.

With the above required turbine overspeed protection system otherwise inoperable, within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months isolate the turbine from the steam supply.

SURVE1LLANCE REQUIREMENTS 4.3.8.1 The provisions of Specification 4.0.4 are not applicable.

4.3.8.2 The above required turbine overspeed protection system shall be demonstrated OPERABLE:

W At least once per # days b d a.-

N CCycling each of the following valves through at least one complete cycle from the running position:

)

". it. ;.. _,..;,..^..^.........^.. '.,;^

Four high pressure turbine b valves, end-1) 2)

Four low pressure turbine interceptor valves ared t

31 6'oer Iow 9'emr* bv'b*'n* iMern'tdMe 94 *,p volvss -

t' r..

ti ;!;;^_. :..! :....,::: "M; ; _i- -- d t';

i

.i.... 1...

.,..f t :p ;,;^-,

1)

_- ' ';'. ; ;;;.:; t rS; t'. ;^ t !; :^ ;. ;'. ; _,

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' sI. F,....

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-'_;;.;I ;.,

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3 A

1

. 1

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b..37 W w

,w.

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f.

im.

---* -- a 2-2A

_-._m._

.-s

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i RIVER BEND - UNIT 1 3/4 3-106

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y 4

INSTRUMENTATION SURVi11lANCf REQUIRIMINT5 (Continued) t.

i ':::' : :: ;:- 22 1:y: i; dir;;; :i;; :ti: :' t': =.;;;

5 NEPLACI

' ;' ti; ;i;.;. 1..; t'...,,,.; ;,,,,,,,, g,. ;,,1, ',

w p gg it:... _, ;; ; i t i -,

( 0.

^^ ?:::t

;:- 1" r:-it: $3 ;; '; : -_:: c' ; ::":"' cf,;;r :;;:,

c' ti; t.riin ;.;r:;;; ;.;;;;i... ';....._...; m,

At least once per 40 months by disassembling at least one of each of d.

the above valves and performing a visual and surface inspection of all valve seats, disks and stems and verifying no unacceptable flaws r :n::::::: :: :::'.

If unacceptable flaws -

oo**ee*en-are found, all other valves of that type shsll be inspected.

1

b. Al leas 4 ons.t Per 14 dew by

1. Arr4 ermine.

c. mecknattal overseerd 4cd (eil Me) af he EHe. Panet.

2. Perler

.A.

a eleelei; I overspeeJ +ve4 af Os EWL Paw e l.

c. A4 leas 4 cc cer 31 eave av evemve. ss.si, s ne son 4,el valves 4kre g A a4 l eni4 ene semple 4a c.ycle

~

4rea. ne rwan'as posmew.

1 e

RIVER BEND - UNIT 1 3/4 3-107

I EMERGENCY CORE C00t!NO SYSTEMS wkU'l 3/4 5.2 ECCS - SHUTOOWN LIMITING CONDITION FOR OPERATION 3.5.2 At least two of the following shall be OPERABLE:

The low pressure core spray (LPCS) system with a flow path capable a.

of taking suttien from the suppression pool and transferring the water through the spray sparger to the reactor vessel, b.

Low pressure coolant injection (LPCI) subsystem "A" of the RHR system with a flow path capable of taking suction from the suppres-sion pool and transferring the water to the reactor vessel.

Lowpressurecoolantinjection(LPC}) subsystem"B"oftheRHR c.

system with a flow path capable of taking suction from the suppres-sion pool and transferring the water to the reactor vessel.

i d.

Low pressure coolant injection (LPCI) subsystem "C" of the RHR l

l system with a flow path capable of taking suction from the suppres-(

sien pool and transferring the water to the reactor vessel.

The high pressure core spray (HPCS) system with a flow path capable e.

of taking suction from one of the following water sources and trans-ferring the water through the spray sparger to the reactor vessel:

1.

From the suppression pool, or 2.

When the suppression pool level is less than the limit or is drained, from the condensate storage tank containing at least 125,000 available gallons.cf water, equivalent to a level of 33.2%.

APPLICABILITY: OPERATIONAL CONDITION 4 and 5*.

ACTION:

With one of the'above required subsystems / systems inoperable, restore a.

at least two subsystems / systems to OPERABLE status within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months or suspend all operations that have a potential for draining the reactor vessel.

With both of the above required subsystems / systems inoperable, suspend b.

CORE ALTERATIONS and all operations that have a potential for draining the reactor vessel.

Restore at least one subsystem / system to OPERABLE j

(

status within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months or establish ^^ ^;in. CONTAIMENT INTEGRITY. ipapTM

{

within the next 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months .

N "lhe ECCS is not required to be OPERABLE provided that the reactor vessel head is removed, the cavity is fluoded, the upper containment fuel pool gates are removed, the spent fuel pool gates are removed, and water level is mainteirmd within the limits of Specification 3.9.8 and 3.9.9.

RIVER BEND - UNIT 1 3/4 5-6

EMERGENCY CORE COOLING SYSTEMS 3/4.5 3 SUPPRESSION POOL

[

LIMITING CONDITION FOR OPERATION 3.5.3 The suppression pool shall be OPERABLE:

In OPERA 110NAL CONDil10N 1, 2 and 3 with a contained water volume ut a.

at least 137,571 2

ft, equivalent to a level of 19'6".

b.

In OPERATIONAL CONDITION 4 and 5* with a contained water volume of at least 115,879 3

ft, equivalent to a level of 16'2", except that the suppression pool level may be less than the limit or may be drained provided that:

1.

No operations are performed that have a potential for draining the reactor vessel, 2.

The reactor mode switch is locked in the Shutdown or Refuel

position, 3.

The condensate storage tank contains at least (125,000) avail-able gallons of water, equivalent to a level of 33.2%, and 4.

The HPCS system is OPERABLE per Specification 3.5.2 with an OPERABLE flow path capable of taking suction from the conden-sate storage tank and transferring the water through the spray sparger to the reactor vessel.

APPLICABILITY: OPERATIONAL CONDITIONS 1, 2, 3, 4 and 5*.

ACTION: -

a. ' In OPERATIONAL CONDITION 1, 2 or 3 with the suppression pool water level less than the above limit, restore the water level to within the limit within I hour 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.

In OPERATIONAL CONDITION 4 or 5* with the suppression pool water level less than the above limit or drained and the above required conditions not satisfied, suspend CORE ALTERATIONS and all operations that have a potential for draining the reactor vessel and lock the reactor mode switch in the Shutdown position. Establish 466eN64iw CONTAINMENT INTEGRIT}within8 hours.

Faismasy C - Se4WTOoWN l

I "The suppression pool is not required to be OPERABLE provided that-the reactor vessel head is removed, the cavity is flooded (or being flooded from the suppression pool), the upper containment fuel pool gates are removed 7 the spent fuel pool gates are removed (when the cavity is flooded), and the water level is maintained within the limits of Specification 3.9.8 and 3.9.9.

RIVER BEND - UNIT 1 3/4 5-8

DRM CONTAINHENT SYSTEMS PalMntV CONTAINMEN1 lhTERNAL PRESSURE l

LIMITING CONDITION FOR OPERATION Prim e r, infer % l 3.6.1.7[/ontainment t :::: cr,

^ i- :-i d:

-t':' pressure shall be maintained between - M and + M psif.

(0.S\\

is.D 9

APPLICABILITY: OPERATIONAL CONDITIONS 1, 2 and 3.

ACTION; Withthe(containmentt:

[n4ereef W " * *Y

: :: c r, _ _ - ^... --.. ^. : -: ' '.. ^... ' p re s s u re o u t s i de o f the specified limits, restore the differential pressure to within the limits within I hour or be in at least NOT 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 .

SURVEILLANCE REQUIREMENTS

, PNm6 ef enternat 4.6.1.7 The4 containment ^-

' pressure shall be determined to be within the limits at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

4 l

RIVER BEND - UNIT 1 3/4 6-11

CONTAINMENT Sv5TEMS ORYVELL AND CONTAINMENT PURGE SYSTEM I

LIMITING CONDITION FOR OPERATION

3. 6.1. 9 The containment purge 36 inch supply and exhaust isolation valves shall be OPERABLE and/ stesse taccer 2

E::' ?! '-f a'..

.t.'.' L.... :... :.....

a y.

Each 36 inch purge valve may be open for purge system operation with such operation limited to 90 hours0.00104 days 0.025 hours 1.488095e-4 weeks 3.4245e-5 months per 365 days for reducing airborne activity and pressure control, asvot HMStetT A A APPLICABILITY: OPERATIONAL CONDITIONS 1, 2 and 3.

f,, w e b e 90 seers Per 365 ea ys, With a 36-inch containment purge supply and/or exhaust isolation s.

valve (s) ope -- - * -- ':f

'--^f. close and/or seal the 36 inch valve (s) or otherwise isolate the penetration within four hours 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 .

ben &675 treins l'" ** * " *>

b.

With the ^,',,

^

T

_ in operation and/or witheuT INSC RT 6 4 M ^^^ - -

t, discontinue 36 inch purge system operation and close the open 36 inch valve (s) or otherwise isolate the penetration (s) within four hours 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 .

~

c.

With a containment purge supply and/or exhaust isolation valve (s)

- with resilient material seals having a measured leakage rate exceeding the limit of Surveillance Requirement 4.6.1.8.3 and/or 4.6.1.8.4, restore the inoperable valve (s) to OPERABLE status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-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 .

SURVEILLANCE REQUIREMENTS 4.6.1.9.1 Each 36 inch containment purge supply and exhaust isolation valve shall be verified to be sealed closed at least once per 31 days.

4.6.1.9.2 The cumulative time that the 36 inch containment purge supply and/or exhaust isolation valves have been open during the past 365 days shall be determined at least once per 7 days.

~

RIVER 8END - UNIT 1 3/4 6-13

~

e-DIN k i.

INSERTS pon page gjy g,.l3 TAM ER T A 1

b. II 4hs 5675 es sw O s pume / low pan 4 ken both frains e4 4ke Sc. T5 en n y be OPf tASLE and owcy owe fre*se of 56TS be opeca b3 en uc porqe (lw pan.

Tusrer 8 1

ben 5675 O PERA8LE suin ene 5 67s

,. u.

per9e Slow ps%,

\\

f t

m

CONTAINMENT SYSTEMS ORYWELL VENT AND PURGE

_ LIMITING CONDITION FOR OPERATION i

3.6.2.7 The drywell vent and purge system supply and exhaust valves shall b closed *^^- ^- -

~1;_.,.

:; _ -, except ' '.

T;^^';^. m

';^,,^f the drywell vent and purge systen. 24 inch valves may be open during ope purge mode of the containment cooling system (igf Jt e drgedl vent and during personnel entries or for controlling drywell press 3

r or to and 12w CWip];or controlling drywell pressure 5. :_,for up to 5 hours5.787037e-5 days 0.00139 hours 8.267196e-6 weeks 1.9025e-6 months per 365 days '- 0^

'::':0^$ ' _ : C

_ C8"

N

--; ti.

C'.

- - - ' _ _ ^

^ ' :, : ;_,_ :,,',

)

', :-_ ' ' :_, 4

._,__1

^i.

APPLICABILITY:

OPERATIONAL CONDITIONS 1, 2 and 3.

ACTION:

i 1

o:.m.<_

s_

__s

_ _.__. __-. __..-,,,,... ; _ ; ;'.....'_.-;'...- __ __ __ _ : ~ ". -

_7__

2__;me_.

7,_

2_

. ^.:.

_. _,_i__.;' - __ ;- 1

c t ' : : _ t ": ' ! "

~

C '.. :- _. '_:

^

GL ar.

during OPERATIONAL CONDITIONS 1 and 2 for i

l en 365 days, immediately close the drywell vent valves or be in at least i

j HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

or.m

<_.m m-e--

";.;,;;;f.,, _

m ;~~

m _._

_,r - _, ' _ - " '

_: _ :_-. ;.:: _: T_

_ _; t _

L_.

.r i

b st.

With the drywell vent or purge mode of the containment cooli in operation during OPERATIONAL CONDITION 3 for more than 90 hours0.00104 days 0.025 hours 1.488095e-4 weeks 3.4245e-5 months ng system per 365 days, immediately close the drywell vent and purge 24 inch valves or be in at least COLD SHUTDOWN within the next 24 m

RIVER BEND - UNIT 1 3/4 6-24

EhCLOSURE 2 MISSING INFORMATION IN REGARD TO RIVER BEND TECHNICAL SPECIFICATIONS i

First Draft Page No.

Item Description 3/4 3-6 Footnote (h) - 1st stage pressure 3/4 3-20 Iten 1.(c) - Purge Isolation Radiation 3/4 3-21 Items 4(c) & (d) - Area Temperature 3/4 3-22 item 5(1) - MSL Timer 3/4 3-24 Isolation Response Tines 3/4 3-25 Isolation Response Times 3/4 3-37 Item 1(h) - Delay Time 3/4 3-38 Items 1(e) & (f) - Flow and Delay Time 3/4 3-39 Item 1(f) -Pressure. Item 0 - Loss of Power 3/4 3-40 Item D - Loss of Power 3/4 3-59 Items (c))& (d) - Water Levels & 4(a)(b) - Setpoint 3/4 3-68 Items 3(a 3/4 3-80 Remote Shutdown Systems 3/4 3-89 Fire Protection Instruments 3/4 3-96 Action 101 - ( ) values 3/4 6-5 Item (f) - ( ) values 3/4 6-9 Items (2.2), (c) & (d) - ( ) values 3/4 6-19 LCO (b) - ( ) values 3/4 6-22 LC0 - ( ) values 3/4 6-65 SR(a) - ( ) values 3/4 6-XX H Igniters - Complete Table 3/4 7-14 S$ubber Sample Plan 3/4 7-31 Area Temperature Mooitors - Complete Table 3/4 7-34 Figure or Table - Structural Settlement 3/4 8-17 MCCs identification 3/4 8-20 MCCs Identification 3/4 8-35 Primary / Secondary Overcurrent Devices 3/4 8-37 MOV Thermal Overload Protection 3/4 8-40 Over/Under Voltage on Bus B 4

i

[

o UNITED STATES p

g 3

g NUCLEAR REGULATORY COMMISSION t

a wAssiscioN. o. c. 20sss t

i February 14, 1985

%,...l../

Docket No. 50-458 LICENSEE: Gulf States Utilities Company FACILITY: River Bend, Unit 1

SUBJECT:

SUMMARY

OF SITE VISIT JANUARY 28-31, 1985 TO DISCUSS TECHNICAL SPECIFICATIONS The staff visited the River Bend site on January 28-31, 1985 to discuss Technical Specifications for the plant. The attendee list for this meeting is enclosed (Enclosure 1). A copy of markup pages (2) to the Technical Specifications as provided by GSU are also enclosed (Enclosure 2).

The technical specification discussion at the site was based on the following documents:

(1) GSU Technical Specifications submittal of July 17, 1984 as supplemented by markup pages on November 1,1984 and January 10, 1985 and (2) NRC first draft of River Bend Technical Specifications dated January 10, 1985. All sections of the River Bend Technical Specifications were discussed in detail and approximately 200 action items were identified. Of these items, further infomation or analysis must be provided by GSil on about 20. GSU was infomed that Technical Specification revisions based on these submittals could not be implemented until proper documentation had been submitted by them and the NRC staff had completed their safety evaluation. Two new specifications were discussed:

(1) flood protection to address surveillance requirements of the bem around the Unit 2 excavation and (2) the program for biofouling prevention and detection (Corbicula-Asiatic Clams).

With the exception of Section 6 (Administrative Controls), the action items will be resolved by the Technical Specification reviewer with appropriate input from the NRR technical reviewer. For Section 6, GSU submitted re-visions to Chapter 13 of the FSAR in a letter dated January 24, 1985 to support their proposed section in the technical specifications.

J. Jaudon (Reg. IV) discussed the deficiencies i.n this submittal and the proposed administrative controls and provided guidance to GSU to resolve the issue.

Our revision to the Technical Specifications in this section will await Region IV review and approval of a future GSU submittal.

Based on the above discussion, the staff will proceed to prepare the second draft of River Bend Technical Specifications. The schedule for issuance of this draft, tentatively set for on or about February 27, 1985, may be impacted due to the outstanding items awaiting GSU submittals.

D&Nk M. Dean Houston, Project Manager

@@h(jFyN-5 f f' gcy,1caipg,fga on Review Group n

Enclosures:

As stated cc: Service List b~h

River Bend Station Mr. William J. Cahill, Jr.

Senior Vice President River Bend Nuclear Group Gulf States Utilities Company Post Office Box 2951 Beaumont, Texas 77704 ATTN:

Mr. J. E. Booker cc: Troy B. Conner, Jr., Esq.

Ms. Linda B. Watkins/Mr. Steven Irving Conner and Wetterhahn Attorney at Law 1747 Pennsylvania Avenue, N. W.

355 Napoleon Street Washington, D.C.

20006

- Baton Rouge, Louisiana 70802 Mr. William J.-Reed, Jr.

Director - Nuclear Licensing Gulf States Utilities Company

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Post Office Box 2951 Beaumont, Texas 77704 Mr. David Zaloudek Nuclear Energy Division H. Anne P1ettinger Louisiana Department of 3456 Villa Rose Dr.

Environmental Ouality Baton Rouge, Louisiana 70806 Post Office Box 14690 Baton Rouge, Louisiana 70898 Richard M. Troy, Jr., Esq.

Assistant Attorney General in Charge State of Louisiana Department of Justice 234 Loyola Avenue New Orleans, Louisiana, 70112 Mr. J. David McNeill, III Dwight D. Chamberlain William G. Davis, Esq.

Resident Inspector Department of Justice

. Post Office Box 1051 Attorney General's Office St. Francisville, Louisiana 70775 7434 Perkins Road Baton Rouge, Louisiana 70808 Gretchen R. Rothschild Louisianians for Safe Energy. Inc.

1659 Glenmore Avenue Baton Rouge, Louisiana 70775 James W. Pierce, Jr., Esq.

P. O. Box 23571 Baton Rouge, Louisiana 70893

J 6

River Rend Technical Specification Meeting January 28-31, 1985 NRC GSU E. Butcher (1/28,29)

J. Price S. Brown (1/28,29)

D. Williamson F. Eltawila (1/28,29)

J. Cutchin C. Schulten (1/28-30)

J. Jaudon Reg. IV D. Houston GSU Consultant Other W. Culp (SWEC)

T. Elwood (Clinton)

T. Szabo (SWEC)

D. Phares (Clinton)

B. Connell (SWEC)-

J. Woodford (GE)

C. Alm (NES) 5 I

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CONTAINMENT SYSTEMS j

CONTAIPe4ENT AVERAGE AIR TEMPERATURE l

LIMITING CONDITION FOR OPERATION i.e 3.6.1.8 Containment average air temperature shall not d*xceed 40*f.

APPLICABILITY: OPERATIONAL CONDITIONS 1, 2 and 3.

ACTION:

With the containment average air temperature greater than N'F, reduce the average air temperature to within the limit within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months or be in at least NOT 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 .

SURVEILLANCE REQUIREMENTS

4. 6.1. 8 The containment average air temperature shall be the (arithmetical) average of the temperatures at the following locations and shall be determined to be within the limit at least once per 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months s:

Elevation Azimuth

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RIVER BEND - UNIT 1 3/4 6-12

l CONTAINMENT SYSTEMS DRYVELL AVERAGE AIR TEMPERATURE LIMITING CONDITION FOR OPERATION swo*

3.6.2.6 Drywell average air temperature sh'all'not exceed MS*F.

APPLICABILITY: OPERATIONAL CONDITIONS 1, 2 and 3.

ACTION:

two*

With the drywell average air temperature greater than MS*F, reduce the average air temperature to within the limit 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 .

SURVEILLANCE REQUIREMENTS 4.6.2.6 The drywell average air temperature shall be the (arithmetical) average of the temperatures at the following locations and shall be determined to be within the limit at least once per 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months s:

Elevation Azimuth a.

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NUCLEAR REGULATORY COMMISSION W ASHINGTON, D. C. 20555

%...../

FEB 8 1985 Docket No.-

50-458 APPLICANT: Gulf States Utilities Company (GSU)

FACILITY:

River Bend Station (RBS)

SUBJECT:

SUMMARY

OF MEETING TO DISCUSS RBS TECHNICAL SPECIFICATION The meeting was held in Bethesda Maryland on January 10, 1985. A list of persons participating in the meeting is included as Enclosure 1.

The generic pathway and milestones for developement of technical specifications was handed out and is included as Enclosure 2.

The first draf t of the RBS technical specifications was completed in early January and will be r.cdified as a result of neetings with GSU to reflect plant specific differences between the standard technical specifications and RBS design.GSU was informed that the FSAR will need to be updated to reflect plant design, programs and organizations prior to final technical specification approval. A meeting on site the week of January 28, 1985 was established. This meeting will be used as a vehicle to discuss further the first draf t and the plant specific differences.

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AL 0 =_='

E ward J. Wei kam III, Project Manager Licensing nch No. 2 Division of Licensing

Enclosures:

As stated cc: See next page U4 -

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TECH SPECS

_ RIVER BEND STATION January 10, 1985 Bethesda, MD i

NAME ORGAN 17ATION Eddie R. Grant GSU Licensing John E. Price GSU Licensing Dan Williamson GSU - Plant Staff Donald S. Brinkman NRC Jorge Flores NRC Carl S. Schulten NRC Dean Houston NRC Ed Butcher NRC Edward Weinkam NRC l

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UNITED STATES 1

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NUCLEAR REGULATORY COMMISSION 3

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WASHINGTON, D. C. 20555 e

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December 6, 1984 Docket No. 50-458 LICENSEE: Gulf States Utilities Company FACILITY: River Bend, Unit 1

SUBJECT:

SUMMARY

OF SITE VISIT ON NOVEMBER 1 AND 2, 1984 TO DISCUSS TECHNICAL SPECIFICATIONS On November 1 and 2,1984, the staff visited the River Bend site to tour the facility and to discuss the developement of technical specifications for the plant. The site tour was conducted by personnel fror GSU. The technical specification discussion was attended by representatives of NRC, GSU and GSU consultants. The attendee lists for both days are enclosed (Enclosures 1 and 2). A copy of a GSil handout used for the technical specification meeting is also enclosed (Enclosure 3) plus replacement pages for their draft of River Bend Technical Specifications (Enclosure 4).

On the first day, the tour included the reactor building, auxiliary building, radwaste building, control building, diesel generator building, ultimate heat sink, turbin'e building, fire protection pump house, fuel building and the cooling tower area. During the lunch break, the group met with T. Plunkett (Plant Pgr.) to discuss the nature of the visit and the anticipated schedules for the plant completion and licensing actions. On the second day, the group briefly toured the training center which contains the EOF and plant simulator.

The process (at GSU) for the development of River Bend Technical Specifications was discussed which showed the interface between the utility and the A-E, NSSS and consultants and the procedures for development, review and resolution of concerns (Enclosure 3). The utility utilized Nuclear Energy Services, Inc.

(NES) as a consultant to generate their first draft of technical specifications.

This draf t also had input from the A-E (Stone and Webster) and the NSSS vendor (General Electric). Within GSU, the development and review of technical specifications is the responsibility of a Reactor Engineer Supervisor who is also a licensed SRC on River Bend. At the conclusion of the meeting, GSU provided some marked up pages of River Bend Technical Specifications (Enclosure 4) which are replacement pages to be inserted in their submittal of July 17, 1984 h.AEe M. Dean Houston, Project Manager Technical Specifications Review Group Division of Licensing

Enclosure:

As stated CC: See next page

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l River Bend Statier Mr. William J. Cahill, Jr.

Senior Vice President 4

River Bend Nuclear Group Gulf States Utilities Company Post Office Box 2951 Beauront, Texas 77704 ATTil: Mr. J. E. Booker cc: Troy B. Conner, Jr., Esq.

Ms. Linda B. Watkins/Mr. Steven Irving Conner and Wetterhahn Attorney at Law 1747 Pennsylvania Avenue, N. W.

355 hapoleon Street Washington, D.C.

20006

_ Baton Rouge, Louisiana 70802 Mr. Willian J. _ Reed, Jr.

Director - Nuclear Licensing Gulf States Utilities Company Post Office Box 2951 Beaunont, Texas 77704 Mr. David 7aloudek Nuclear Energy Division H. Anne Plettinger Louisiana Departnent of 3456 Villa Rose Dr.

Environmental Ouality Baton Rouge, Louisiana 70806 Post Office Box 14690 Baton Rouge, Louisiana 70898 Richard M. T oy, Jr., Esq.

Assistant Atte 1ey General in Charge State of Louisiana Department of Justice 234 Loyola Avenue New Orleans, Louisiana, 70112 Mr. J. David McNeill, III j

Dwight D. Chamberlain William G. Davis, Esq.

Resident Inspector Department of Justice Post Office Box 1051 Attorney General's Office St. Francisville, Louisiana 70775 7434 Perkins Road Baton Rouge, Louisiana 70808 Gretchen R. Rothschild Louisianians for Safe Energy, Inc.

1659 Glenmore Avenue Ba. ton Rouge, Louisiana 70775

'Jaces W. Pierce, Jr., Esq.

P. O. Box 23571 Baton Rouge, Louisiana 70893 1

1 i

Site Tour Attendees

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Main Plant Tour November 1,1984 I

NRC GSU S. Brown T. Overlied (Tour Guide)

J. Flores D. Williamson D. Houston J. Price C. Schulten B. Reed

E. Weinkam P. Grahan*

R. Trowbridge*

T. Plunkett (Plant Mgr.)*

-Partial Participation Training Center Tour November 2,1984 NRC GSU t

S. Brown B. Reed O. Chamberlain (SRI)

J. Price J. Flores D. Williamson 4

D. Houston B. Odell 1

E. Weinkam i

C. Schulten l

GSU Consultant l

B. Price i

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Attendees Technical Spacification Meeting November 2, 1984 NRC GSU S. Brown E. Grant J. Flores B. Reed D. Houston J. Price C. Schulten D. Williamson E. Weinkam T. Overlied GSU Consultant C. Alm I

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-

ML20132C788

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