ML20209E489

Discusses Review of Final Draft Tech Specs.Util 850506 Submittal Contained Numerous Deficiencies & Acts of Omission & commission.Marked-up Draft Tech Specs Indicating Errors Encl

ML20209E489
Person / Time
Site:	River Bend
Issue date:	05/17/1985
From:	Houston M NRC - TECH SPEC REVIEW GROUP
To:	Butcher E, Butcher F NRC - TECH SPEC REVIEW GROUP
Shared Package
ML20209E496	List: IA-85-511, Discusses Remarks Re Util Awareness of Errors,Discrepancies & Problems in Current Tech Specs.Caution Should Be Employed in Final Audit & Review of App A.Util Already Demonstrated Inability to Identify All Errors in Final Draft ML20209E489 ML20209E497 ML20212K372 ML20212K376 ML20212K388 ML20212K400 ML20212K411
References
FOIA-85-511 NUDOCS 8505300310
Download: ML20209E489 (50)

Text

.

o,,

UNITED STATES

. g.

g NUCLEAR REGULATORY COMMISSION g

p WASHINGTON, D. C. 20555 k.,

/

May 17, 1985 i

MEMORANDUM FOR: Edward J. Butcher, Group Leader i

Technical Specification Review Group Division of Licensing FROM:

M. Dean Houston, Reactor Engineer

-Technical Specification Review Group Division of Licensing

SUBJECT:

DEFICIENCIES IN REGARD TO GSU CERTIFICATION OF RIVER BEND TECHNICAL SPECIFICATIONS (FINAL DRAFT)

By letter dated May-2, 1985, Gulf States Utilities (GSU) was requested to review the final draft of River Bend Technical Specifications and submit by May 13, 1985, a. certification under oath and affimation that the final draft accurately. reflects the FSAR, SER and as-built configuration of.the plant. By letter dated May 6,1985 GSU submitted their certification, under oath and affimation, of the final draft of River Bend Tech Specs.

Included in their submittal were:

(1) identified editorial changes-(173 items), (2) proposed changes to the Tech Specs (38 items)..(3) proposed-revisions to the SER (7 items) and (4) identification of FSAR sections 4 -

to be revised with some proposed FSAR revisions (55 areas).

In my review of their submittal, numerous deficiencies, acts of omission and comission, have been identified. Examples of editorial errors that were i

not identified by GSU are presented in Enclosure 1.

The attached pages are from the GSU submittal, some with their markup, and the errors that were not detected are circled. These errors take many foms - typos, missed.

headings, non-existent trip signals, nomenclature, etc. While misspelled words can be properly interpreted, many of the other unidentified errors would have contributed to operator confusion..The enclosure is not. intended

. to be a complete compf k tion of-overlooked errors but does establish that the GSU review process was less than thorough. Approximately 20% of the

~

errors in the final draft were not-detected during their review. This is i

an unacceptable level by'any standard and their review process for certi-fication at' licensing must be improved.

Examples of deficiencies by acts of comission are presented in Enclosure 2.-

Two of these are editorial errors and one is based on a possible false statement regarding their as-built plant.

(1) GSU proposed changes to page 3/4 8-5 of the River Bend.

Tech Specs as shown. As proposed, the change was to be inserted between 10 and seconds. On page 3/4 8-6 of the e

Edward J. Butcher May 17, 1985 same submittal, GSU properly proposed an identical change with the clause to be inserted after 10 seconds. As pr.oposed on 3/4 8-5, the revision makes no sense and would confuse the operator.

(2) In Attachment B of the GSU submittal of May 6,1985, Item 29 requests a deletion of a surveillance requirement because -

"There are no valves in the flow path of any PGCC subsystem."

In past discussions, GSU has resisted this requirement on the basis that the valves did not have a position indicator although, in fact, the valves do have a trip indicator. A copy of FSAR Figure 9.5-13 is enclosed which shows numerous solenoid operated valves as well as a couple of check valves in the flow path. Therefore, the GSU statement of "no valves m

in the flow path" appears to be a false representation.

(3) Also, in Attachment B Item 30 refers to adding a footnote to TS 3/4.7.6.4 Table 3.7.6.4-1.

This is in error as the proposed footnote _was identified with TS 3/4.7.6.5, Table 3.7.6.5-1.

In addition to the deficiencies noted above, I would like to comment briefly on other uncertainties associated with the River Bend Tech Spec review.

GSU has submitted a listing of 55 areas in the FSAR that need revision to support Tech Spec, sections. Amendment 19.to the FSAR was delivered on May 14, 1985 and only 12 of these areas were addressed. Therefore, in the other 43 areas, the NRR Technical Reviewer has not seen the necessary documentation to support the current Tech Spec section or a proposed revision to a section. There is also the potential for additional FSAR revisions resulting from the reviewer's evaluation. This lack of timely infomation will impact the accelerated schedule for issuance of the Tech Spec: with the River Bend license in June, 1985.

There seem to be some values in the FSAR and Tech Specs that are constantly being changed. For example, the DBA activity release to the environment following a LOCA (used for containment Tech Spec review) were revised in Amendment 18 to the FSAR dated April 1985 and revised again (increased) in Amendment 19 on May 13, 1985.

In the Tech Specs, GSU has pro the water level for the Ultimate Heat Sink be 112'4" (2nd Draft) posed that

, 108"6" (Final Draft) and 111'10" (current revision). Changes of this frequency would indicate that the utilities review process has not settled down.

All of the above matters should be given due considerations when discussing commitments and completion schedules for the River Bend Tech Specs.

N.

Y

~

M. Dean Houston, Reactor Engineer Technical Specification Review Group Division of Licensing cc:

D. Crutchfield R. Benedict S. Stern

L M @SSURE 1

~

FINAL DRAFf TECHNICAL SPECIFICATIONS RIVER BEND - UNIT 1 Markup Pages From GSU Submittal of 5/6/85 Errors not identified by GSU are circled and noted in margin with L Not Intended To Be Complete April 26, 1985

Sa1, t-S FINAL DRAFT s

BASES 2.1.3 REACTOR COOLANT SYSTEM PRESSURE The Safety Limit for the reactor coolant s; stem pressure has been selected such that it is at a pressure below which it can be shown that the integrity of the system is not endangered.

The reactor pressure vessel is designed to Section III of the ASME Boiler and Pressure Vessel Code 1971 Edition, including Addenda through Summer 1973, which permits a maximum pressure transient of 110%,

1375 psig, of design pressure, 1250 psig. The Safety Limit of 1325 psig, as measured by the reactor vessel steam dome pressure indicator, is equivalent to 1375 psig at the lowest elevation of the reactor coolant system. The pressure Safety Limit is selected to be the lowest transient overpressure allowed by the ASME Boiler and Pressure Vessel Code,Section III, Class I.

2.1.4 REACTOR VESSEL WATER LEVEL

~

With fuel in the reactor vessel during ' periods when the reactor is shut sideration _must be given to water level requirements due to the effect eca-eat.

If the water level should drop below the top of the active irradi-1 during this period, the ability to remove decay heat is reduced.

This reduction in cooling capability could lead to elevated cladding tempera-tures and clad perforation in the event that the water level became less than two-thirds of the core height. The Safety Limit has been established at the top of the active irradiated fuel to provide a point which can be monitored and also provide adequate margin for effective action.

i W

m i s lses RIVER BEND - UNIT 1 B 2-5 e-.

,g

.tIMXTING SAFETY SYSTEM SETTINGS BASES

!1 REACTOR PROTECTION SYSTEM INSTRUMENTATION SETPOINTS (Continued) -

the water level has reached a point high enough to indicate that it is indeed filling up, but the volume is still great enough to accommodate the water from the movement of the rods when they are tripped.

The trip setpoint for each I

scram discharge volume is equivalent to a contained volume of approximately 17 gallons of water.

10. Turbine Stop Valve-Closure The turbine stop valve closure trip anticipates the pressure, neutron flux, and heat flux increases that would result from closure of the stop valves.

With a trip setting of 5% of valve closure from full open, the resultant increase in heat flux is such that adequate thermal margins are,

maintained during the worst case transient.

11. TurbineControlValveFastClosure, Trip 011 Pressure-Low The turbine co~ntrol valve fast closure trip anticipates the pressure, neutron flux, and heat flux increase that could result from fast closure of

' tbine control. valves due to load rejection with or without coincident [

^2 :

ailure of the turbine bypass valves.

The Reactor Protection System

('

mmates a trip when fast closure of the control valves is initiated by the fast acting solenold valves and in less than 20 milliseconds after the start of control valve fast closure. This is achieved by the action of the fast acting solenoid valves in rapidly reducing hydraulic trip oil pressure at the main turbine control valve actuator disc dump valves.

This loss of pressure is sensed by pressure switches whose contacts form the one out-of-two twice logic input to the Reactor Protection System. This trip setting, a slower clofure time, and a different valve characteristic from that of the turbine stop valve, combine to produce transients which are very similar to that for the stop valve.

Relevant transient analyses are discussed in Section 15.2.2 of the Final Safety Analysis Report.

12.

Reactor Mode Switch Shutdown Position The reactor mode switch Shutdown position is a redundant channel to the automatic protective instrumentation channels and provides additional manual reactor trip capability.

13. Manual Scram The Manual Scram is a redundant channel to the automatic protective instrumentation channels and provides manual reactor trip capability.

(

j

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RIVER BEND - UNIT 1 8 2-9 APft 2 61585

\\

REACTIVITY CONTROL SYSTEMS LIM' TING CONDITION FOR OPERATION (Continued) i ACTION:

(Continued)

~

4.

No " slow" control rod, " fast" control rod with individual scram inser-I tion time in excess of the limits of ACTION a.2, or othemise inoperable i

control rod occupy adjacent locations in any direction, including the diagonal, to another such control rod.

g Otherwise, be in at least HOT SHUTDOWN within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

b.

With a " slow" control rod (s) not satisfying ACTION a.1, above:

l 1.

Declare the " slow" control rod (s) inoperable, and i

2.

Perform the Surveillance Requirements of Specification 4.1.3.2.c at least once per 60 days when operation is continue,d with three or more " slow" control rods declared inoperable.

~

Othemise, be in at least HOT SHUTDOWN within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

l t

c.

With the maximum scram insertion time of one or more control rods exceed-ing the maximum scram insertion time limits of Specification 3.1.3.2 as determined by Specification 4.1.3.2.c, operation may continue provided that:

[~ ~.

1.

" Slow" control rods, i.e., those which exceed the limits of t-(

Specification 3.1.3.2, do not make up more than 20% of the 10%

l-sample of control rods tested.

2.

Each of these " slow" control rods satisfies the limits of ACTION a.1.

3.

The eight adjacent control rods surrounding each " slow" control rod are:

a)

Demonstrated through measurement within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> to satisfy the maximum scram insertion time limits of Specification 3.1.3.2, and b)

OPERABLE.

4.

The total number of " slow" control rods, as determined by Specifica-tion 4.1.3.2.c when added e sum of ACTION a.3, as determined by Specification 4.1.3.2.

does not exceed 5.

g Otherwise, be in at least HOT SHUTDOWN within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />, d.

The provisions of Specification 3.0.4 are not applicable.

k AP9 2 61985 RIVER BEND - UNIT 1 3/4 1-7 e

o

I REACTIVITY CONTROL SYSTEMS 1"

]

g t

j a

CONTROL ROD SCRAM ACCUMULATORS LIMITING CONDITION FOR OPERATION ACTION:

(Continued)

~

a)

Electrically, or b)

Hydraulically by closing the drive water and exhaust water isolation valves.

2.

With mor ne withdrawn control rod with the associated X9 scram cu@ato inoperableandwithnocontrolroddrivepump[

operating, immediately place the reactor mode switch in the Shutdown position.

The provisions of Specification 3.0.4 are not. applicable.

c.

4.1.3.3.Each-control rod scram accumulator shall be determined OPERABLE:

At least once per 7 days by verifying that the indicated pressure is a.

greater t_han or equal to 1520 psig unless the control rod is inserted and disarmed or scrammed.

b.

At least once per 18 months by:

1.

Per.formance of a:

a)

CHANNEL FUNCTIONAL TEST of the leak detectors, and b)

CHANNEL CALIBRATION of the pressure detectors, and verifying an alarm setpoint of 1520 psig on decreasing pressure.

'~

2.

Verifying th'at each individual accumulator check valve maintains the associated accumulator pressure above the alarm set point for greater than or equal to 10 minutes, starting at normal system operating pressure, with no control rod drive pump operating.

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RIVER BEND - UNIT 1 3/4 1-10

INSTRUMENTATION

~

6 4

• 3/4.3.2 ISOLATION ACTUATION INSTRUMENTATION LIMITING CONDITION FOR OPERATION The isolation actuation instrumentation channels shown in Table 3.3.2-1 3.3.2 shall be OPERABLE with their trip setpoints set consistent with the values shown in the Trip Setpoint column of Table 3.3.2-2 and with ISOLATION SYSTEM RESPONSE TIME as shown in Table 3.3.2-3.

APPLICABILITY: As shown in Table 3.3.2-1.

ACTION:

With an isolation actuation instrumentation channel trip setpoint a.

less conservative than the value shown in the Allowable values column of Table 3.3.2-2, declare the channel inoperable until the channel is restored to OPERABLE status with its trip setpoint adjusted,

. consistent with the Trip Setpoint value.

b.

With the number o OPERABLE Channel RABLE channels less than required by the Minimum place the inopera ip System requirement for one trip system, M

condition

• within one hour.hanne1(s) and/or that trip system in the tripped I

The provisions of Specification 3.0.4 are not applicable.

With the number of OPERABLE channels less than required by the Minimum c.

OPERABLE Channels per Trip System requirement for both trip systems, place at least one trip system ** in the tripped condition within one hour and take the ACTION required by Tabic 3.3.2-1.

"An inoperable channel need not be placed in the tripped condition where this would cause the Trip Function to occur.

In these cases, the inoperable channel Table 3.3.2-1 for that Trip Function shall be taken.shall be restored t

• • The trip system need not be placed in the tripped condition if this would cause the Trip Function to occur.

When a trip sy' tem can be placed in the tripped condition without causing the Trip Function to occur, place the trip system with the most inoperable channels in the tripped condition; if both systems have the same number of inoperable channels, place either trip system in the tripped condition.

iP8i e a ses -

RIVER BEND - UNIT 1 3/4 3-10 I

W 9

Y h twil.aj-j[]g TABLE 3.3.2-1 (Continued) asNPeam ISOLATION ACTUATION INSTRUMENTATION ACTION ACTION 20 8e in at least NOT SHUTOOWN within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDOWN within the next 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

~

tl Close the affected system isolation valve (s) within one hour or:

[l ACTION 21

l a.

In OPERATIONAL CONDITION 1, 2, or 3, be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in entn m iTnnwy I;

within the following 24 hou

,/

InOperationalConditionh,suspendCOREALTERATION5',

b.

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 <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> or be in at least NOT SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

~

~

ACTION 23 Be in at least STARTUP with the associated isolation valv^es clossd within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> or be in at least HOT SHUTDOWN within t

12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDOWN within the next 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

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

I ACTION 25 Establish SECONDARY CONTAINHENT INTEGRITY - OPERATING with the

\\

standby gas treatment 'systeIan4 nel s.g within one hour.bcqwymeL) operatin

.uc$ ventil.% syew

,l ACTION 26 Restore the manual initiation function to OPERA 8LE status within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> or be in at least HOT SHUTDOWN within the next l

12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

i 1

ACTION 27 Close the af'fected system isolation valves within one hour and declare the ~affected system inoperable.

ACT2eu 2s - ENsani HEH.

=

ACTION 46 5:t h' f:5 !!C^"C.^"" C^"'^.!"":"' !"TEC"!TV afth th: :t: Q, ;::

21 tr::t ::t :;;r:tf ; aftt' Initiate and maintain annulus mixing system with the reactor building annulus exhaust l

to at least one operating standby gas treatment train within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.

ACTION 46 -

Lock the affected system isolation valves closed within one 30 hour3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br /> and declare the affected system inoperable.

(

yR 2 6 W-RIVER BEND - UNIT 1 3/4 3-17 E

w.,

.-e-.,,

, _.. +

)

TABLE 3.3.2-3 ISOLATION SYSTEM INSTRUMENTATION RESPONSE TIME TRIP FUNCTION RESPONSE TIME (Seconds)#

1.

PRIMARY CONTAINMENT ISOLATION

< 10(f*)

a.

Reactor Vessel Water Level - Low Low, Level 2 s

a) t b.

Drywell Pressure - High

< 10 Containment Purge Isolation Radiation - High(b) 7 10(a) g c.

d.

Manual Initiation RA I

2.

MAIN STEAM LINE ISOLATION l

t-a.

Reactor Vessel Water Level - Low Low Low, Level 1

< 1.0 */< 10(a),,

Main Steam Line Radiation - High(b)

I 1.0 */7 10('))**

I b.

c.

Main Steam Line Pressure - Low I 1.0 */7 10 a,,

g

. _ ~ '

d.

Main Steam Line Flow - Hi h I 0.5 */7 10(a),,

~

Main Steam Line Tunnel

n., 7,4 Condenser Vacuum - Low 77 WA

~

e.

f.

NA g.

Main Steam Line Tunnel A Temperature - High NA

(

h.

Manual Initiation NA i

1 3.

SECONDARY CONTAINMENT ISOLATION j

a.

Reactor Vessel Water Level - Low Low, Level 2

< 10(a) j b.

Drywell Pressure - High 7 10(a) a Fuel Building Ventilation Exhaust Radiation - High(b) 10( )

c.

d.

Reactor Building Annulus Ventilation Jeunes Exhaust Radiation - High(b)

< 10(a) t e.

Hanual Initiation NA

[

4., REACTOR WATER CLEANUP SYSTEM ISOLATION a.

A Flow - High

< 10(a)##

b.

A Flow Timer 5A c.

Equipment Area Temperature - High NA d.

Equipment Area A Temperature - High NA e.

Reactor Vessel Water Level - Low Low, Level 2

< 10,)

I f.

Main Steam Line Tunnel Ambient

~

Temperature - High NA g.

Main O--

' '- Tundel A Temperature - High NA h.

SLCSCniti[ tion]

NA 1.

Manua, Ani usuon NA S.

REACTOR CORE ISOLATION COOLING SYSTEM ISOLATION a.

RCIC Steam Line Flow - High

< 10(*)###

b.

RCIC Steam Line Flow-High Timer WA c.

RCIC Steam Supply Pressure - Low

< 10 ")

I d.

RCIC Turbine Exhaust Diaphragm Pressure - High EA RCIC Equipment Room Ambient Temperature - High NA-e.

a f.

RCIC Equipment Room A Temperature - High NA

(

g.

Main Steam Line Tunnel Ambient Temperature - High NA h.

Main Steam Line Tunnel A Temperature - High NA RIVER BEND - UNIT 1 3/4 3-24 APft 2 61985

-- l

, ry,

(

r TABLE 4.3.2.1-1 (Continued) l10

• 2 ISOLATION ACTUATION INSTRUMENTATION SURVEILLANCE REQUIREMENTS 9

m CHANNEL OPERATIONAL T

CHANNEL FUNCil0NAL CHANNEL CONDITIONS IN WHICH TRIP FUNCTION CllECK TEST CALIBRATION SURVEILLANCE REQUIRED e

3.

SECONDARY CONTAINMENT ISOLATION Z

a.

Reactor Vessel Water Level - Low Low, tevel 2 5

M R

1, 2, 3 b.

Drywell Pressure - High 5

M R

1, 2, 3 tas s a e. L a __ u n f c.

Fuel Building Apee venttiatiorF s M

R

_h2':_a d.

Reactor Building Annulus Ventilation Exha Radiation - Hig S

M,)

R 1,2,3 3

g e.

Manual Initiation NA H

NA 1,2,3

~..... j w

4.

REACTOR WATER CLEANUP SYSTEM ISOLA' ION s

[

a.

A Flow - High S

M R

1, 2 3 g

b.

a Flow Timer NA M

Q 1,2,3 c.

Equipment Area Temperature -

High S

M R

1,2,3 d.

Equipment Area a Temperature - High 5

M R

1,2,3 e.

Reactor Vessel Water R ")

1, 2, 3 I

Level - Low Low, level 2 S

M f.

Main Steam Line Tunnel Ambient

~

Temperature - High S

M R

1, 2, 3 m91 g.

Main Steam Line Tunnel CJ a Temperature - High 5

M R

1, 2, 3 h.

SLCS Initiation NA M(b)

NA 1,2,3 g

1.

Manual Initiation NA M(a)

P m

NA I, 2, 3 tm

.T

• 0 Da

'N saw) 1

f' 9

r

-Q' TABLE 3.3.6-2 CONTROL R00 BLOCK INSTRUMENTATION SETPOINTS E

m TRIP FUNCTION TRIP SETPOINT ALLOWABLE VALUE 4.L b 1.

R00 PATTERN CONTROL SYSTEM ie a.

Low Power Setpoint 27.5 i ATED TilERMAL POWER 27.5 i.

RATED THERMAL

-.),

c POWE

/

4 b.

High Power Setpoint 62.5 ATED THERMAL POWER 62.5 i ATED THERMAL POWER w

2.

APRM a.

Flow Biased Neutron Flux

- Upscale

< 0.66 W + 42%"

< 0.66 W + 45%*

b.

Inoperative HA NA c.

Downscale

>5% of RATED THERMAL POWER 1 3% of RATED THERMAL POWER d.

Neutron Flux - Upscale Startup

$ 12% of RATED THERMAL POWER

$ 14% of RATED THERMAL POWER 3.

SOURCE RANGE MONITORS w

a.

Detector not full in NA NA 5

5 2

b.

Upscale

$ 1 x 10 cps 1.6 x 10 cp, w

c.

Inoperative NA NA d.

Downscale 1 0.7 cps 1 0.5 cps **

g 4.

INTERMEDIATE RANGE MONITORS a.

Detector not full in NA NA b.

Upscale

$ 108/125 division of full 5 110/125 division of full scale scale c.

Inoperative NA NA d.

Downscale

-> 5/125 division of full

-> 3/125 division of full scale scale "T1 mass 5.

SCRAM DISCHARGE VOLUME sg.*~

a.

Water Level-High

< 18 inches

< 22 inches 6.

REACTOR COOLANT SYSTEM RECIRCULATION FLOW a.

Upscale i 108% of rated flow

$ 111% of rated flow n

• The Average Power Range Monitor rod block function is varied as a function of recirculation loop flow (W). M The trip setting of this function must be maintained in accordance wjth Specification 3.2.2.

9

• • Provided signal to noise ratio is 1 2, otherwise setpoint of 3 cps and allowable 1.8 cps.

"T1 m

5

i TABLE 4.3.7.2-1 SEISMIC HONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTS N

CHANNEL CHANNEL FUNCTIONAL CHANNEL INSTRUMENTS AND SENSOR LOCATIONS CNECK TEST CALIBRATION

~

1.

Triaxial Time-History Accelerographs a.

Reactor Bldg.

70'0" M

SA R

b.

Reactor 81dg hield Wall M

SA R

g EL 232'0" c.

Reactor Bldg. Drywell EL 151'0" M SA R,

d.

Free Field-Grade Level M

SA R

2.

Triaxial Peak Accelerographs 4

a.

Reactor Bldg. SLCS Storage Tank NA NA R

b.

Reactor Bldg. - RHR Inj. Piping NA NA R.

Aux. 81dg. Service Water Piping NA NA R

c.

3.

Triaxial Seismic Switches a.

Reactor 81dg. Mat EL 70'0" M(a)

SA R

4.

Triaxial Resportse-Spectrum Recorders 1

[. - i a.

Reactor Bldg. Mat EL 70'0' M

SA R

\\

b.

Reactor 81dg. Floor EL 141'0" NA SA R

Auxiliary Bldg. Floor ELAuxiliary Bldg. Hat EL 70'

',0" c.

NA NA R

v d.

41 NA NA R

(a)Except seismic trigger.

AF't 161985 RIVER BEND - UNIT 1 3/4 3-72 O

INSTRUMENTATf0N FIL1 DRAFT METEOROLOGICAL MONITORING INSTRUMENTATION g

LIMITING CONDITION FOR OPERATION Themefteorologicalmonitoringinstrumentationchannelsshownin Q' l e.

3.3.7.3 Table 3.3.7.3-1 shall be OPERABLE.

si

^ ^ ^ ' "' S' ' T TY: At all times.

k ith one or more meteorological monitoring instrumentation channels inoperable for more than 7 days, prepare and submit a Special Report to the Commission pursuant.to Specification 6.9.2 within the next 10 days outlining the cause of the malfunction and the plans for f

restoring the instrumentation to OPERABLE status.

2' b.

The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.

I' s

SURVEILLANCE REQUIREMENTS I

i h-4.3.7.3 Each of the above required meteorological monitoring instrumentation channels shall be demonstrated OPERABLE by the performance of the CHANNEL CHECK and CHANNEL CALIBRATION operations at the frequencies shown in Table 4.3.7.3-1.

i-5 s

4 l<

I f

b

. RIVER BEND - UNIT 1 3/4 3-73 D 2 81985

s X

' FINAL DRAFT a"=

a t

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h

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t

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2 2

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R G

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=s

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2. E E

222 22:

E E

=

=

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==

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a e'

>=

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h g

88

=

e

T

- f E

EE

=

l 8

3

<=v t

3 )

u na &

EE 3

3 I88 u

22 u

3 i

i 2

3

=

t 9

3 9

g i

hl c

8 8

h 2

B 3

e, t.

1t S

Ei 8

8 E

5 a

'5 g

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t 33 b

i C,

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=

m

=

W W

J '

R E

2 E

o E

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W M

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g u

u E

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>=

CL CL

=

M N

M T

b nah N

N N

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RIVER BEND - UNIT 1 3/4 3-77 APR 2 61985 4

^

FINAL DRAFT A

TABLE 3.3.7.4-2 REMOTE SHUTOOWN SYSTEM CONTROLS MINIMUne cuau sts an y e Giv. JJ:QDiv.E.h 1.

RCIC Suction from CST MOV 1

NA (IE51*MOVF010) 2.

RCIC Injection Shutoff MOV 1

NA (IE51*MOVF013) 3.

RCIC Min. Flow to Suppression 1

NA Pool MOV (1E51*MOVF019) 4.

RCIC Test Bypass to CST MOV 1

NA (1E51*MOVF022) 5.

RCIC Gland Seal Air Compressor 1

NA (1E51*PC002C)

~

6.

RCIC Pump Suction from Suppression

.t.

e4 Pool MOV (1E51*MOVF031)

Y 4A-7.

RCIC Steam to Turbine MOV 1

NA (1E51*MOVF045) 8.

RCIC Turbine Lube Oil Cooling MOV 1

NA (1E51*MOVF046)

F

-Wr-(,

9.

RCIC Test Bypass to CST MOV 1

NA (1E51*M0VF059)

\\

10.

RCIC Steam Supply Inboard Isolation 1

NA MOV(IE51*MOVF063) 11.

RCIC Steam Supply Outboard Isolation 1

NA MOV(1E51*MOVF064)

, s s,,,

12.

RCIC Turbine Exhaust to Pool 1

NA

~~

MOV(1E51*MOVF068) 13.

RCIC Steam Line Warmu;i Line Isolation 1

NA MOV(IE51*M0VF076) 14.

RCIC Vacuum Breaker Outboard Isolation 1

NA MOV(1E51*MOVF077) 15.

RCIC Vac um Breaker Inboard Isolation 1

NA MOV(1 VF078) 16.

RCIC Turbine Flow Controller 1

NA (IC61*FICR001) 17.

RCIC Turbine Trip & Throttling MOV 1

NA (1E51*MOVFC002) li W.

RHR Pump 1

2(,)

(1E12*PC002A, 28, 2C)

~10 M.

RHR Hx Shell Side Outlet MOV 1

1 (1E12*MOVF003A,8) 18 Mr.

RHR Pump Suction MOV 1

2(,)

(1E12*MOVF004A, 8; 1E12*MOVF105) g2,)

NA zen.

Et.

RHR Shutdown Cooling MOV 5

(1E12*MOVF006A,68)

18. Reic Tu, ame gaf Seluf SJ,4ek i

gf4 (a) One per control equipment RIVER BENO - UNIT 1 3/4 3-78 N

l I

I TABLE 3.3.7.4-2 (Continued)

REMOTE SHUTDOWN SYSTEM CONTROLS

\\

MINIMUM ruauurt< r - : e

{DIV. Y.EgDIV.II 2/3.2P:

RHR Outboard Shutdown Isolation MOV 1

NA jj (1E12*MOVF008)

/rN N/

w R.

RHR Inboard Shutdown Isolation MOV 1

NA j f e c /,r f w we '

(1E12*MOVF009) g

,f RHR Hx Flow to % g[ u n;.

o1 MOV 1

1 u -24.

(1E12*MOVF011A, B)

My 7/8 24 ffr.

RHR Reactor Head Spray MOV 1

NA (IE12*MOVF023)

I. - I u 26.

RHR Test Line MOV 1

1 gy (1E12*MOVF024A,8) m.

tr 27.

RHR Hx Flow to RCIC MOV 1

NA J-X (1E12*MOVF026A)

M G&.

RHR Injection Shutoff MOV 1

1 (lE12*HOVF027A,B)

~

so 49.

RHR Upper Pool Cooling Shutoff MOV 1

1 (1E12*MOVF37A,B) 3: Be.

RHR Injection MOV 1

2(,)

(1E12*MOVF042A,B,C)

11. M.

RHR Hx Shell Side Inlet MOV 1

1 (IE12*MOVF047A,8)

(

37 32. RHR Hx Shell. Side Bypass MOV 1

1 (1E12*M0VF048A,B)

.\\

sy 93. RHR Discharge to Radwaste MOV 1

NA (1E12*MOVF040) 3r 34.

RHR Steam Isolation MOV 1

1 (1E12*H0VF052A, B) 24 36.

RHR Injection MOV 1

1 (IE12*MovF053A,B) 17 Sfr.

RHR Pump Minimum Flow'MOV 1

2(,)

(1E12*MOVF064A, B, C) or W.

RHR Hx Water Discharge MOV 1

1 (1E12*MOVF068A,B) si 9&.

Safety Relief Valves 3(,)

3(,)

(1821*RVF051, C, G D) af. W.

SSW Pump 14-2(a)

(ISVP*P2A, 2(.T 2B, 20)

• f t 40.

Normal Service Water Isolation MOV 1

1 (ISWP"MOV96A,B) 5:144.

SSW Cooling Tower Inlet MOV 1

1 (ISWP"MOV55A,B)

(a) done per control equipment (b) 5 5 w rw-p iswa = P2c. as a Divissoo IIT c.~,,,a. L.mt w,,i h ! 61985 RIVER BEND - UNIT 1 3/4 3-79 es gr.widad.

9

~.

.. -. _ _ _.. =..

s I

[

y g

1

/

.T_ARLE 4. 3. 7. 5-1 A

mq ACCIDENT MONITORING INSTRUMENTATION SURVEILL m

m TS en 5"

INSTRUMENT CHANNEL.

CHANNEL APPLICA8tE

[

1.

Reactor Vessel Pressure

~

_ CHECK CALIBRATION OPERATIONAL x

2.

U Reactor Vessel Water Level M

CONDITIONS a.

Wide Range R

1, 2 w

b.

Fue) Zone M

3.

Suppression Pool Water Level Me 1, 2 R

4.

Suppression Pool Water Temperature R

M' 1, 2 3

." :._., C..L :. -... A 7

M R

.L..

R 1, 2,1 6.

1 Primary Containment Pressu,re 1, 2,1 7.

Drywell Pressure.

M i, 2_

{

8.

Drywell Air Temperature M

R R

1, 2 9.

Drywell and Primary Containment Hydrogen Concentration M

1, 2 Analyzer and Monitor M

R Y

10.

Safety / Relief Valve Po Q*

1, 2 Area Radiatfor.* T.;_.sition Indicators 1, 2 11.

k Y

• 1?.

Ce..L ;. a.. ;./0, M

":nt'unt"ut2!:n,C:!;.;"_c.'t;.'_11'rd R

I 13.

4 4-1, 2 "x :. p !;'?d'r;M x ? ": d!' ; a

-1, 2

r;: "u t'?:::

1, 2, 3-S' r r, "n Tr::tn-t 5,;t:. !;!;;;; ";..'t;.,

l'.

O" Cn

":-'t r,:xd ":i;nt: ";'?d' ; "n!:t':

5:t : ; t-1, 2, 3' t

1, 2, ---

15.

T;- i'm 5;' ?d' g "n!::: "t;;':; ? g i:i:

c u- - r, -

1;t p

~~~

1, 2, 3 sing sample gas containing:

One volume percant hydrogen, balance nitrogen.

a.

i Four volume percent hydrogen, balance nitrogen.

• y

}

pd m==

detector, for range decades above 10 R/hr ahe CHANNEL CALIBRATION shall co M=

t ration of the channel, not including the g

with an installed or portable gaan.a source.nd a one point calibration check of the detector be Jo y

High range ;L'; ;-' monitors, w

r grm gaeama i

%g r ta c a. p,.iny ca M-+ A"n 6:W 24D

~

b. Drwell Area R

'M %

y R

I,2., ~%

FI3NA:! N 'l TABLE 3.3.7.8-1 (Continued)

.=

s J dy ij FIRE DETECTION INSTRUMENTATION s

INSTRUMENT LOCATION TOTAL INSTRUMENTS OPERABLE

• HEAT FLAME SM0KE (x/y)

(x/y)

(x/y)

I.

CONTROL BUILDING ZONE (Continued) g.

50-143 PGCC PMEL MODULE, EL 136'0" 0/9 17/0 50-144 PGCC PANEL MODULE, EL 136'0" 0/9 17/0 50-145 PGCC PANEL MODULE, EL 136'0" 0/8 8/0 50-146 PGCC PANEL MODULE, EL 136'0" 0/8 8/0 50-147 PGCC PANEL MODULE, EL 136'0" 0/12 14/0 50-148 PGCC PANEL MODULE, EL 136'0" 0/12 18/0 50-149 PGCC PANEL MODULE, EL 136'0" 0/10 14/0 m

50-150 PGCC PANEL MODULE, EL 136'0" 0/9 15/0 50-151 PGCC PANEL MODULE, EL 136'0" 0/10 10/0 50-158 PGCC PANEL MODULE, EL 136'0" -

0/8 8/0 50-152 NON PANEL MODULE AREA NORTH, EL 135'0" 10/0 50-153 NON PANEL AREA SOUTH, EL 135'0'"

10/0 50-154

' lR.tL AREA, EL 136' 84/0 g-50-162 REMOTE SHUTDOWN PANE t

EL 98'0" C.~

50-163 REMOTE SHUTDOWN P 1/0 IV

[

EL 98'0" 1/0 FD-2/i CHARC0AL FILTER 1HVC"FLT38, EL 115'0" 1/0 FD-27 CHARCOAL FILTER 1HVC"FLT3A, EL 115'0" 1/0 II.

REACTOR BUILDING

• • ZONE 50-57

1. CONTAINMENT AREA, EL 114'0" eM-13/o 50-102 ANNULUS AREA, EL 186'3" GNG-21Vo 6-50-104

1. CONTAINMENT AREA, EL 186'3" 17/0 50-117

1. CONTAINMENT AREA, EL 162'3" 64-7/o 50-119

1. CONTtINM S*T AREA, EL 141'0" 13/0 S0-156

1. CONTAINHENT AREA, EL 95'9" 2/0 FD-13

1. RECIRC PUMPS - DRYWELL, EL 70'0"

& 98'0" 2/0 i

5

• (x/y): x is number of Function A (early warning fire detection and notifi-cation only) instruments.

y is number of Function 8 (actuation of fire suppression systems and early warning fire detection).

1. The fire detection instruments located within the Containment are not required to be OPERABLE during the performance of Type A Containment Leakage Rate Tests.

RIVER BEND - UNIT 1 3/4 3-89 AP9181!ES

_TA8LE 3.3.7.10-1 (Continu:d)

TA8tE NOTATION ACTION 100 -

With the number of channels OPERABLE less than required by the Minimum Channels OPERABLE requirement, effluent releases may continue for up to 14 days provided that prior to initiating a release:

i At least two independent samples are analyzed in accordance a.

'with Specification 4.11.1.1.1,and b.

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

~

ACTION 101 -

With the number of channels OPERABLE less than required by the i

Minimum Channels OPERA 8LE requirements, effluent releases via this pathway may continue for up to 30 days provided that, at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />, grab samples are collected and analyzed for gross radioactivity (beta or gaesa) at a limit of detection of at least 10 7 sic ocuries/al.

ACTION 102 -

With the number of channels OPERA 8LE less than required by the

[

Minimum Channels Opraan'"

quirement, effluent releases via this pathway may

/

rate is estimatec{nontinuq/3orupto30daysprovidedtheflow h Pump curves generated in situ may be used to estimate flow,..nr. on i

b 6

l l

4 se RIVER 8END - UNIT 1 3/4 3-96

,.,,.-.-_--,-,.,..--.-_,__n---

- _.-- ~,

TABLE 4.3.7.10-1 (Continued)

FINAL. DRAFT TABLE NOTATION s

i, (1) The CHANNEL FUNCTIONAL TEST shall also demonstrate that automatic isolation of this pathway occurs if any of the following conditions exists:

1.

Instrument indicates measured levels above the alarm / trip setpoint.

I 2.

Circuit failure.

T'-

^

(2)fnnf;iatthecurs if any of the following conditions exists:. C'"'

FUNCTIONAL TEST shall also demonstrate that control room alarm 1.

Instrument indicates measured levels above the alarm setpoint.

p 2.

Circuit failure.

3.

Instrument indicates a downscale failure.

4.

Instrument, controls not set in operate mode.

(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 C, :

calibrating th'e system over its intended range of energy and measurement

,s range.

For subsequent CHANNEL CALIBRATION, sources that have been related to the initial calibration shall be used.

(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 <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> on

.. days which continuous, periodic, or batch releases are made.

en RIVERBEND-UNIT 5 3/4 3-98 W 2 6 74

TA8LE 4.3.7.11-1 (Continued)

TABLE NOTATIONS At all times.

During main condenser offgas treatment systes operation.

0..-;r.i, go. tier. ;f th n f^ :;.d; =;r cir ;j;;ter.

(1[)":fiatiohcurs if any of the following conditions ^"~"' FUNCTIONAL nn exists:

y

/

1.

Instrument indicates measured levels above the alarm setpoint.

2.

Circuit failure.

3.

Instrument indicates a downscale failure.

~

4.

Instrument controls not set in operate mode.

(2)

The initial CNANNEL 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 sensurement assurance activities with NBS.

calibrating the systee over its intended range of energy and measurementT i

to the initial calibration shall be used.For subsequent CHANNEL CAL range.

(3)

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.

l RIVER BEND - UNIT 1 3/4 3-105 EI8 9

i

".]NSTRUMENTATION 3/4. 3. 9 PLANT SYSTEMS ACTUATION INSTRUMENTATION LIMITING CONDITION FOR OPERATION

~

3.3.9 The plant systems actuation instrumentation channels shown in Table 3.3.9-1 shall be OPERABLE with their trip setpoints set consistent with the values shown in the Trip Setpoint column of Table 3.3.9-2.

APPLICABILITY: As shown in Table 3.3.9-1.

ACTION:

With a plant system actuation instrumentation channel trip setpoint a.

2 less conservative than the value shown in the Allowable Values column of Table 3.3.9-2, declare the channel inoperable and takie the ACTION required b Table 3.3.9-1.

b.

With one or mor plarif

' stems actuation instrument channels inoperable, take the-ACTION red by Table 3.3.9-1.

w SURVEILLANCE REQUIREMENTS 4.3.9.1 Each plant system actuation instrumentation channel shall be demonstrated CPERABLE by the performance of the CHANNEL CHECK, CHANNEL FUNCTIONAL TEST and CHANNEL CALIBRATION operations for the OPERATIONAL CONDITIONS and at the frequencies shown in Table 4.3.9.1-1.

4.~3.~9.2 LOGIC SYSTEM FUNCTIONAL TESTS and simulated automatic operation of all channels shall be performed at least once per 18 months.

(

RIVER BEND - UNIT 1 3/4 3-108 APR 2 61985

REACTOR COOLANT SYSTEM t

3/4.4.2 SAFETY VALVES SAFETY / RELIEF VALVES LIMITING CONDITION FOR OPERATION 3.4.2.1 The safety valve function of at least 5 of the following the relief valve function of at least 4 additional valves of.tbehollo#

)

other than those satisfying the safety valve function requiremen. mai s ce es OPERABLE with the specified lift settings:

Number of Valves Function Setpoint" (osic) 7 Safety 1165 1 1%

5 Safety 1180 2 1%

4 Safety 1190 1 1%

1 Relief 1103 1 15 psig 8

Relief 1113 2 15 psig 7

Relief -

1123 2 15 psig The acoustic monitor for each OPERABLE valve shall be OPERABLE.

APPLICABILITY: OPERATIONAL CONDITIONS 1, 2 and 3.

ACTION:

(

^

i With the safety and/or relief valve function of one or scre of the above a.

required safety / relief valves inoperable, be in at least HOT SHUTDOWN within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDOWN within the next 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

b.

With one or more safety / relief valves stuck open, provided that suppres-sion pool average water tem open safety / relief valve (s)perature is less than 105'F, close the stuck

~~

if suppression pool average water temperature.

is 105'F or greater, place the reactor mode switch in the Shutdown position.

With one or more safety / relief valve acoustic monitors inoperable, restore c.

the inoperable monitor (s) to OPERABLE status within 7 days or be in at least NOT SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDOW the following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

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

s Ng g 61985 RIVER BEND - UNIT 1 3/4 4-5 r

l REACTOR COOLANT SYSTEM

\\

3/4.4.5 SPECIFIC ACTIVITY LIMITING CONDITION FOR OPERATION o

l 3.4.5 The specific activity of the primary coolant shall be limited to:

Less than or equal to 0.2 microcuries per gram DOSE EQUIVALENT a.

I-131, and

• '~

b.

Less than or equal to 2004 microcuries per gram.

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

[' ~

ACTION:

In OPERATIONAL CONDITIONS 1, 2 or 3 with the specific activity of a.

the primary coolant; 1.

Greater than 0.2 microcuries per gram DOSE EQUIVALENT I-131 but less than or equal to 4.0 microcuries per gram, operation may continue for up to 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> provided that the cumulative opera-tirig time under these circumstances does not exceed 800 hours0.00926 days <br />0.222 hours <br />0.00132 weeks <br />3.044e-4 months <br /> in any consecutive 12-month period. With the total cumulative

('

operating time at a primary coolant specific activity greater than 0.2 microcuries per gram DOSE EQUIVALENT I-131 exceeding 500 hours0.00579 days <br />0.139 hours <br />8.267196e-4 weeks <br />1.9025e-4 months <br /> in any consecutive six-month period, prepare and submit a Special Report to the Commission pursuant to Specification 6.9.2 within 30 days indicating the number of hours of operation above this limit.

The provisions of Specification 3.0.4 are not appli-cable.

2.

Greator than 0.2 microcuries per gram DOSE EQUIVALENT I-131 for more than 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> during one continuous time interval or for more than 800 hours0.00926 days <br />0.222 hours <br />0.00132 weeks <br />3.044e-4 months <br /> cumulative operating time in a consecutive 12-month period, or greater than 4.0 microcuries per gram, be in at least NOT SHUTDOWN with the main steam line isolation valves closed within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

3.

Greater than 100 4 mi n.. ['

gram, be in at least HOT SHUTOOWN with the mai stea ne solation valves closed within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

b.

In OPERATIONAL CONDITIONS 1, 2, 3 or 4, with the specific activity of the primary coolant greater than 0.2 microcuries per gram DOSE EQUIVALENT I-131 or greater than 100/E microcuries per gram, perform the sampling and analysis requirements of. Item 4a of Table 4.4.5-1 until the specific activity of the primary coolant is restored to within its limit.

A REPORTABLE EVENT shall be prepared and sub-mitted to the Commission pursuant to Specification 6.6.1.

This report shall contain the results of the specific activit? analyses RIVER BEND - UNIT 1 3/4 4-16 vst51!E5 1

i

~

REACTOR COOLANT SYSTEM

\\

3/4.4.7 MAIN STEAM LINE ISOLATION VALVES LIMITING CONDITION FOR OPERATION OPERABLE with closing times greater than o((MSIV 3.4.7 Two main steam line isolation valv

-- h steam line shall be k 3pand ss_t.han or equal g

to 5 seconds.

der,4c/.s APPLICABILITY: OPERATIONAL CONDITI0NS 1, 2 and 3.

ACTION:

With one or more MSIVs inoperable:

a.

1.

Maintain at least one MSIV OPERABLE in each affected main steam line that is open and within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />, either:

a). Restore the inoperable valve (s) to OPERABLE status, or b)

Isolate the affected main steam line by use of a deacti-vated MSIV in the closed position.

(_ '

2.

Otherwise, be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTOOWN within the following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

b.

The provisions of Specification 3.0.4 are not applicable.

SURVEILLANCE REQUIREMENTS 4.4.7 Each of the above required MSIVs shall be demonstrated OPERABLE by verifying full closure between 3 and 5 seconds when tested pursuant to Specification 4.0.5.

The provisions of Specification 4.0.4 are not applicable for entry into OPF. RATIONAL CONDITIONS 2 or 3 provided the surveillance is performed within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after reaching a reactor steam pressure of 600 psig and prior to entry into OPERATIONAL CONDITION 1.

RIVER BEND - UNIT 1 3/4 4-25 Y'

l f

FINT'" DPET EMERGENCY CORE COOLING SYSTEMS

\\

SURVEILLANCE REQUIREMENTS 4.5.1 ECCS division 1, 2 and 3 shall be demonstrated OPERABLE by:

At least once per 31 days for the LPCS, LPCI and HPCS systems:

a.

1.

Verifying by venting at the high point vents that the system piping from the pump discharge valve to the sy'sfeTisolation valve is filled with water.

hri 2.

hat each valve, manual, power operated or automatic n

.....,. sow path that is not locked, sealed, or otherwise secu, red 1

in position, is in its correct position.

b.

Verifying that, when tested pursuant to Specification 4.0.5, each:

~

1.

LPCS pump develops a flow of at least 5010 gpm with a pump differential pressure greater than or equal to 281 psid.

LP'CI pump develops a flow of at least 5050 gpm with a pump 2.

differential pressure greater than or equal to 100 psid.

f 3.

HPCS pump develops a flow of at least 5010 gpm with a pump

(

differential pressure greater than or equal to 399 psid.

Y For the LPCS, LPCI and HPCS systems, at least once per 18 months, c.

performing a system functional test which includes simulated automatic actuation of the system throughout its emergency operating sequence and verifying that each automatic valve in the flow path actuates to its correct position. Actual injec-tion of coolant into the reactor vessel may be excluded from this test.

For the HPCS system, at least once per 18 months, verifying that d.

the suction is automatically transferred from the condensate storage tank to the suppression pool on a condensate storage tank low water level signal and on a suppression pool high water level signal, and verifying that the HPCS system will automatically restart on Reactor Vessel Water Level - Low Low, Level 2.

APR 2 61985 RIVER BEND - UNIT 1 3/4 5-4 O

t 1

CONTAINMENT SYSTEMS LIMITING CON 0! TION FOR OPERATION (Continued)

ACTION (Continued) d.

The combined leakage rate for all penetrations shown in Table 3.6.1.3-1 as annulus bypass leakage paths exceeding 13,500 cc/hr, or-t The combined leakage rate, for all valves shown in Jahle.3.6.4-1 to e.

be equipped with PVLCS, exceeding 170,000 cc/hr, or f.

The esasured combined leakage rate for all containment isolation valves in hydrostatically tested lines per Table 3.6.4-1 which penetrate the primary containment exceeding 1 gpa times the total number of such

valves, y.

restore:

The overall integrated leakage rate (s) to less than 0.75 La as a.

applicable, and t

b.

The combined leakage rate for all penetrations and all valves subject i

to Type B and C tests to less than or equal to 0.60 La, and The measured leakage rate to less than 340 scfh for each of the valve c.

groupings identified in 3.6.1.3.c.1, 3.6.1.3.c.2, and 3.6.1.3.c.3 and

(

d.

The combined leakage rate for all penetrations shown in Table 3.6.1.3-1

[

as annulus bypass leakage paths to less than or equal to 13,500 cc The combined leakage rate, for all valves shown in Table 3.6.4-1 to be e.

equipped with PVLCS, to less than or equal to 170.000 cc/hr, and-f.

The combined leakage rate for al16 C

.5. ; dntainment isola-tion valves in hydrostatically tes1.eu

....,m

..eie 3.6.4-1 which penetrate the primary containment to less than or equal to.1 gpm times the total number of such valves, i

prior to increasing reactor coolant system temperature above 200*F.

SURVEILLANCE REQUIREMENTS l

4.6.1.3 The primary containment leakage rates shall be demonstrated at the follow-ing test schedule and shall be determined in conformance with the criteria specif in Appendix J of 10 CFR 50 using the methods and provisions of ANSI N45.4 Three Type A Overall Integrated Containment Leakage Rate tests-shall a.

be conducted at 40 2 10 month intervals during shutdown at Pa, ).6-psig, during each 10 year service period.

The third test of each set shall be conducted during the shutdown for the 10 year plant inservice inspection.

4 m

./

RIVER BEND - UNIT 1 3/4 6-4 5

i

_ _... _.. _.. _.. _,... _ _ _ _ _ _ _ _ _ _ __,,1

p 'yj=Ta CONTAINMENT SYSTEMS

. f Qh[ j s.

MSIV LEAKAGE CONTROL SYSTEM

{

LIMITING CONDITION FOR OPERATION 3.6.1.5 divisions shall be OPERABLE.Two independent main steam positive leakage contro APPLICABILITY; OPERATIONAL CONDITIONS 1, 2 and 3.

---

~~

ACTION:

With one MS-PLCS division inoperable, restore the inoperable division to OPERABLE status within 30 days or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

SURVEILLANCE REQUIREMENTS 4.6.1.5 Each MS-PLCS division shall be demonstrated OPERABLE:

By performing Surveillance Requirement 4.6.1.10.a.

a.

($

b.

At least once a=- " '-~- by verifying compressor OPERABILITY by operat'ingth{ompras caded for at least 15 minutes.

During each COLD SHUTDOWN, if not performed within the previous c.

92 days, by cycling each remote, manual and automatic motor operated valve through at least one complete cycle of full travel.

d.

At least once per 18 months by performance of a functional test which -

includes simulated actuation of the division throughout its operating' sequence, and verifying that each automatic valve actuates to its correct position and that 8.5 t 3 psid sealing pressure is established in each steam line.

l b

3rs 2 s 495 RIVER BEND - UNIT 1 3/4 6-10

i CONTATNMENT SYSTEMS

.l!'l't

. p

==

x ORYVELL BYPASS LEAKAGE

~

LIMITING CONDITION FOR OPERATION 3.6.2.2 Drywell bypass leakage shall be less than or equal to 10% of the minimum acceptable A/ 8 design value of 1.0 ft.2 APPLICABILITY:

When DRYWELL INTEGRITY is required per Specification 3.6.2.1.

ACTION:

A/S design value of 1.0 ft.2,With the drywell bypass leakage greater than 1 restore the drywell bypass leakage to within the limit prior to increasing reactor coolant system temperature above 200 F.

~

SURVEILLANCE REQUIREMENTS

^

4.6.2.2 The drywell bypass leakage rate test shall be per 18 months at an initial differential pressure of 3.

d at least once C.

ps dtheA/4 shall be calculated from the measured leakage.

One d lock door shall remain open during the drywell leakage test such that each drywell door is

\\

leak tested during at least every other leakage rate test.

If any drywell bypass leakage test fails to meet the specified limit, a.

the schedule for subsequent tests shall be reviewed and approved by the Commission.

If two consecutive tests fail to meet the limit, a test shall be performed at least every 9 months until two consecutive tests meet the limit, at which time the 18 month test schedule may be resumed.

b.

The provisions of Specification 4.0.2 are not applicable.

RIVER BEND - UNIT 1 3/4 6-19

EEbNN h%@E U CONTAINMENT SYSTEMS bg LIMITING CONDITION FOR OPERATION (Continued)

ACTION:

(Continued) 2.

With the suppression pool average water temperature greater than:

g a) 95'F for more than 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> and THERMAL POWELgreater than 1% of RATED THERMAL POWER, be in at least HOT SHUTDOWN within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDOWN within the next 24 b) 110*F, place the reactor mode switch in the Shutdown position and operate at least one residual heat removal loop in the suppression pool cooling mode.

1.

With the suppression pool average water teeperature greater than

~

120*F, depressurize the, reactor pressure vessel to less than 200 psig within 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />

)

With only one suppressic c.

water level indicator OPERABLE I

and/or with fewer than eigit suppression pool water temperature indicators, one in each of W eight locations, OPERABLE, restore f.,

the inoperable indin+W to OPERABLE status whithin 7 days or verify suppressie f f t @ ater level and/or temperature to be within the limits

.6 t

ce per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

d.

With no suppressio f - S water level indicators OPERABLE and/or with fewer than seve..wppression covering at least seven locations, pool water temperature indicators, OPERABLE, restore at least one water level indicator and at least six water temperature indicators

~,

to OPERABLE status within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> or be in at least HOT SHUT 00WN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

SURVEILLANCE REQUIREMENTS 1

\\

4.6.3.1 The suppression pool shall be demonstrated OPERABLE:

t By verifying the suppression pool water volume to be within the a.

limits at least once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

b.

At least once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, in OPERATIONAL CONDITION 1 or 2, by verifying the suppression pool average water temperature to be less than or equal to 95'F, except:

1 1.

At least once per 5 minutes, during testing which gdds heat to I

the suppression pool, by verifying the suppression pool average water temperature less than or equal to 105*F.

RIVER BEND - UNIT 1 3/4 6-28

1 CONTAINMENT SYSTEMS

(

SECONDARY CONTAINMENT AUTOMATIC ISOLATION DAMPERS LIMITING CONDITION FOR OPERATION 3.6.5.3 The secondary containment ventilation system automatic isolation dampers shown in Table 3.6.5.3-1 shall be OPERABLE with isolation time; less than or equal to the times shown in Table 3.6.5.3-1.

APPLICABILITY: As shown in Table 3.6.5.3-1.

_ ACTION:

With one or more of the secondary containment ventilation system automatic isolation dampers shown in Table 3.6.5.3-1 inoperable, maintain at least one isolation damper OPERABLE in each affected penetration that is open, and within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> either:

I Restore the inoperable damper (s) to OPERABLE status, or a.

b.

Isolate each affected penetration by use of at least one deactivated

~

automatic damper secured in the isolation position, or Isolate each affected penetration by use of at least one closed maneal c.

valve or blind Tu eGs.o.s ei sp,res. flange. s C v er< 'u c W'"l NL -

/

hmkw Otherwise, in OPERATIONAL CONDITION 1, 2 or 3, be in at least HOT SHUTOOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD DOWN within the following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

[6audvf M/ZVA<) -

Otherwise, in Operational Conditio speno nandling or irra~diated AI S'*ldm$ ;;t: tiei.'mfuel in the '::--de y : -teia e

.t,- CORE ^LTEMT! OMS e*d ^^e-sti:n _ith :

m eir.ing the.;;.;ter ::::1.

The provisions of Specifica-tion 3.0.3 are not applicable.

SURVEILLANCE REQUIREMENTS 4.6.5.3 Each secondary containment ventilation system automatic isolation damper shown in Table 3.6.5.3-1 shall be demonstrated OPERABLE:

Prior to returning the damper to service after maintenance, repair or a.

replacement work is performed on the damper or its associated actuator, control or power circuit, by cycling the damper through at least one complete cycle of full travel and verifying the specified isolation time.

F-tBj.ld.

{

nen irradiated fuel is being handled in the.eeee-dary :: g;im:nt

-d du 4a; n,

40RE ALTERATLM m,; ;;:m + 4 ^~

ith 2 pet:nti:1 'er er:4-4a; +he

- ta- "escal p RIVER BEND - UNIT 1 3/4 6-52 SPE 2 6 Wi

CONTAINMENT SYSTEMS FUEL BUILDING VENTILATION LIMITING CONDITION FOR OPERATION 3.6.5.6 Two independent Fuel Building Ventilation Charcoal Filtration sub-systems shall be fPERABLE, and in QPERATIONAL,CpNDITION,*, one operating in the emergency mode.

'.,,,, 2,.:

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

ACTION:

With one Fuel Building Ventilation Charcoal Filtration subsystem a.

~

inoperable, restore the inoperable subsystem to OPERABLE status' within 7 days, or:

~

1.

In OPERATIONAL CONDITION 1, 2 or 3, be in at least HOT SHUTDOWN wi.thinthenext12hoursandinCOLDSHUTDOWNwithinthefollhing 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

2.

In Operational Condition

• suspend handling of irradiated f el in the :::. f: ;

-aan'- :nt, 00"E ^.LT!".AT!O'S rd :;;r:ti:n;

- S Fuet 8/,(d q ions of Specification 3 0 3- --^:-ti:' ':- fr:i 'r.;

^.h c;::ter.;. nl The provi-s are not applicable, b.

With both Fuel Building Ventilation Charcoal Filtration subsystems inoperable or with one not operating in the emergency mode in Opera-Fuel kleig my ram'n:;.c., 00": ALT.uTION:tional Condition *, suspend handling

:;:--ti: : _ ith :. M...u ci

~~

':r dr;i 'n; th: r; n t:r ;;;;;l.

tion 3.0.3. are'not applicable.

The provisions of Specifica-SURVEILLANCE REQUIREMENTS 4.6.5.6 Each fuel Building Ventilation Charcoal Filtration subsystem shall be demonstrated OPERABLE:

/ w..

e...v At least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> in OfERATIONAL CDHDITION'

• a.

hv verifying one Fuel Building Ventilation Charcoal Filtrat ystem eration.

b.

4 At least once per 31 days by initiating, from the contror room, flow through the HEPA filters and charcoal adsorbers and verifying that the subsystem operates for at least 10 hours1.157407e-4 days <br />0.00278 hours <br />1.653439e-5 weeks <br />3.805e-6 months <br /> with the heaters OPERABLE.

)

8Vi/drr RG' Py c e nt s.Q-; r t Inf L.

"When irraciated fuel is being handled in the ::::

i C0": ALT ""!OS :.! :;; :t ~ "ith : ;;t *ti:1 'er dr:ining th - Z t^T s,

- a a r r-RIVER BEND - UNIT 1 3/4 6-61 JB g g g

t

~

CONTAINMENT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued)

Manual initiation from th_e control room, and a.

b.

Simulated automati ifit(tio signal.

4.

Verifying that the filter coling bypass dampers-ean be manually opened and the fan can be manually started.

5.

Verifying that the heaters dissipate >49 kw when tested in accordance with ANSI' N510-19M(JT80 f.

After each complete or partial replacement of a HEPA filter bank by

^ ~ -

verifying that the HEPA filter bank satisfies the inplace penetration and bypass leakage testing acceptance criterion of less than 0.05% in

~

Accordance with ANSI N510-49M while operating the system at a flow rate of 10,000 cfm t 10%. /9#8 ~

p g.

After each complete or partial replacement of a charcoal adsorber

• bank, by verifying that the charcoal adsorber bank satisfies the e

inplace penetration and bypass leakage testing acceptance criterion of less than 0.05% in accordance with ANSI N510-genated hydrocarbon refrigerant test gas while[o,ttf5 for a halo-

- _i at 'a flow rate of 10,000 cfm i 10%.

perating the system fi ro i

(.

-(

ULTIMATE HEAT SINK

' 'E SURVEILLANCE REQUIREMENTS

4. 7.1. 2 The standby cooling tower and water storage basin shall be OPERABLE:

e At least once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> by terifying the basidE:f t$ ;:r5t a.

en+ water to be within their limits.

urc c y.

At leas r 31 days by starting the cooling tower fans in each cell fr control room and operating the fan for at least 15 minut

( b. Dvein3 k months ef June 'fbmf S*rkk, beMo, A

. hours e{ nsoc ud Itcc vedfy tiu. basin wa,tes,%pajvg af efeab 95 'k W thSL (<ttivuonalely grak elea&d io be belew Hs hMd :

e t,

I. Al kad an p 79 telwr k pavica agu*13

- w-w r 2

a f leasi enet pin.2y hwes whw tk pudns n.es.4h3 was greA4u % 75'r e

/

e 6

(

RIVER BEND - UNIT 1 3/4 7-4 PR 2 61985

PLAN 1 SYSTEMS YARD F]RE HYORANTS AND HYORANT HOSE HOUSES LIM] TING CONDITION FOR OPERATION t

\\

3.7.6.5 z

Table 3.7.6.5-1 shall be OPERABLE.The yard fire hydrants e houses shown in APPLICABILITY:

hydrants is required to be OPERABLEWhenever equipment in the t

i y the yarc fire ACTIOg a.

With one or more of the yard fire hydrants o hose houses shown in Table 3.7.6.5-1 inoperablr associated h sufficient additional lengths of 21/2 inch diameter he, with in an adjacent OPERABLE hydrant hose hou the unprotected area (s) if the inoperable fise to provide service ose located hydrant hose house is the primary means of fire hydrant or as o.therwise provide the additional hose within 24 ho re suppression; b.

The provisions of Specifications 3.0 3 and 3 0 4 urs.

o are not applicable.

SURVE5LLANEE REQUIREMENTS F-4.7.6.5 shown in Table 3.7.6.5-1 shall be demonstrated

\\ s y rant hose houses a.

house to assure all required equipment is a n of the hydrant hose the hose house.

b.

At least once per 6 months, by visually inspe ti fire hydrant and verifying that the hydrant b c

ng each yard that the hydrant is not damaged.

arrel is dry and c.

,At least once per 12 months by:

1.

Conducting a hose hydros

~

or at least 50 psig abov st at a pressure of 150 psig pressure, whichever is g....... he maximum fire main operating 2.

Replacement of all degraded gaskets in coupling-3.

s.

Performing a flow check of each hydrant RIVER BEND - UNIT 1 i

3/4 7-27 APR1 6 EfM l

• i" 9 4 Q'? {t :

"P ELECTRICAL POWER SYSTEMS E

(:

SURVEILLANCE REQUIREMENTS (Continued) 6.

Simulating a loss of offsite power in conjunction with an ECC actuation test signal, and:

a)

For divisions I and II:

1)

Verifying deenergization of the emegifncy busses and load shedding from the emergency busses.

2)

Verifying the diesel generator starts on the auto start signal, energizes the emergency busses with permane connected loads within 10 seconds, energizes the auto-connected d _;d;-n loads through the 4eed sequencing logic and operates for greater than or equal to 5 minutes while its generator is loaded with the

~

emergency loads.

After energization, the steady. state voltage and frequency of the emergency busses shd 1 be maintained at 4160 1 420 this test.

volts and 60 2 3 Hz during b)

For division III:

q; 1)

Verifying de-energization of the emergency bus.

-(

2)

Verifying the diesel generator starts on the auto-p,~

..aly..+4 start signal, energizes the emergency bus with its f..Jr w.d.

to sw/g---9 4:e ;;,4 the auto-connected rm;;n;y loads MtP-ca qle M stre-t and operates for greater than or equal to 5 minutes while its generator is loaded with the emergency loads.

After energization

' voltage and frequency of the emergenc,y bus shall bethe stea maintair.ed at 4160 1 420 j

this test.

volts and 60 2 3 Hz during i

7.

ally bypassed uponVerifying that all automatic diesel generator E

tuation signal except:

a)

For divisio differential ngine overspeed and generator ren.

b)

For divisi n

,/rngine overspeed and generator differential current.

8.

The diesel generators shall be loaded to 3130 kw generator 1A and 18 and 2600 kw for diesel generator IC.

generator voltage and frequency shall be The 4160 2 420 volts and 60 2 3 Hz within 10 seconds after the start signal; the steady

(

RIVER BEND - UNIT 1 3/4 8-6 APR 2 6 N

!i f TABLE 4.8.1.1.2-1

=*L [

_ DIESEL GENERATOR TEST SCHEDULE Numb f Failures in Las 0 Valid Tests

• Test Frecuency

<1 At least once per 31 days 2

At least once per 14 days 3

• ' ~

At least once per 7 days

>4 At least once per 3 days

~

I f

" Criteria for determining number of failures and number of valid

(.

tests shall be in accordance with Regulatory Position C.2.e of Regulatory Guide 1.108, Revision 1, August 1977, where the last 100 tests are determined on a per nuclear unit basis.-

For the purposes of this test schedule, only valid tests conducted af ter

last 100 valid tests.the OL issuance date shall be included in the computatio made at the 31 day test frequency. Entry into this test schedule shall be O

l APR 2 61985 RIVER BEND - UNIT 1 3/4 8-9

TABLE NOTATION N.

continued

(

is the standard deviation of the background co sb cDunting rate of a blank sample as appropriate, as counts per m E is the counting efficiency, as counts per disintegration V is the sample size in units of mass or volume 2.22 x 105 is the number of disintegrations per minute per microcuri Y is the fractional radiochemical yield, when applicable e,

A is the radioactive decay constant for the particular radio

[' '

nuclide, and At for plant effluents is the elapsed time between the mid collection and time of counting.

point of. sample Typica'l values of E, V, Y, and at sh'ould be used in the calc l u ation.

k the fact) limit representing the capability of a mea e ore *,

as an a posteriori (after the fact) limit for a particular measuremen ement system and not r-b - A batch release is the discharge of liquid wastes of a di i

mixed to assure representative sampling.to sampling fo screte volume.

Prior

, and then thoroughly c - The principal gamma emitters for which the LLO specification sively are the following radionuclides:

es exclu-Mo-99, Cs-134, Cs-137, Ce-141, and Ce-144.Mn-54, Fe-59, Co-58, Co-60, 2n-65, only these nuclides are to be considered.

This list does not mean that identifiable, together with those of the above nuclidesOther gamma peak pursuant to Specification 6.9.1.99. analyzed and reported in

, shall also be eport d - A composite s 8

of sampling 6.,$itM}in which the quantity of liquid sampled on tional to th quan results in a specimen that is representativ

,. o liquids released.

RIVER BEND - UNIT 1 APR 2 61985 3/4 11-3

3__

RADIOACTIVE EFFLUENTS

~

LIQUID RADWASTE TREATMENT SYSTEM

(

_ LIMITING CONDITION FOR OPERAT1?N t

3.11.1.3 radioactive materials in liquid astes prior to their projected doses due to the liquid effluent, to UNRESTRICTED AR e

Figure 5.1.3-1) would exceed 0.06 mrem to the total body or 0 2 e

see organ in a 31 day period.

arem to any APPLICABILITY: At all times.

ACTION:

' u.

With radioactive liquid waste being discharged without treatm in excess of above Ifaits, prepare and su ent and within 30 d includes the s pu suant to Specification 6.

t to the Commission a

f owing information:

pecial R.eport that )I 1.

treatment, identification of any inoperable e subsystems, and the reason for the inoperability, 1

[

2.

Action (s) taken to restore the inoperable equipment to O status, and 3.

Summary description of action (s) taken to prevent a recurr b.

The provisions of Specifications 3.0.3 and 3.0.4 are not app e.

SiJRVEILLANCEREQUIREMENTS 4.11.1.3 at least once per 31 days in accordance with the the ODCM.

ce ameters in k

1

\\

RIVER BEND - UNIT 1 APR 2 61985 3/4 11-5 j

y

RACIOLOGICAL ENVIRONMENTAL MONITORING 3/4.12.2 LAND USE CENSUS LIMITING CONDITION FOR OPERATIO 6_ :

f)

3. I2. L

-3.12.1 A land use census shall be conducted and shall identify within a distance of 8 km (5 miles) the location in each of the 16 meteorological sectors of the nearest milk animal, the nearest residence and the nearest garden" of greater than 50 m2 2

(500 ft ) producing broad leaf vegetation.

l APPLICABILITY: At all times.

ACTION:

\\

With a land use census identifying a location (s) that yields a a.

calculated dose or dose commitment greater than the values currently E

being calculated in Specification 4.11.2.3, identify the new location (s) in the next Seminannual Radioactive Effluent Release Report, pursuant tar Specification 6.9.1.8.

~

t b.

Withlandusecensusidentifyingalocation(s)thatyieldsacalcufated dose or dose commitment (via the same exposure pathway) 20 percent-

)

greater-than at a location from which samples are currently being obtainod in accordance with Specification 3.12.1, add the new location (s) to the radiological envirbnmental monitoring program within 30 days.

f The sampling location (s), excluding the control station location, having the lowest calculated dose or dose commitment (s), via the i

i same n ure pa aftehetober3h6., may be deleted from this monitoring program the year in which this land use census was l

condu %.

T..nm. to Specifi:ation 6.9.1,8, identify the new location (s) in the next Seminannual Radioactive Effluent Release Report and also include in the report a revised figure (s) and table for the ODCM reflecting the new location (s),

The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.

c.

SURVEILLANCE REQUIREMENTS 4.12.2 The land use census shall be conducted during the growing season at least once per 12 months using that information that will provide the best results, such as by a door-to-door survey, aerial survey, or by consulting local agriculture authorities.

The 'results of the land use census shall be included in the Annual Radiological Environmental Operating Report pursuant to Specification 6.9.1.7.

• Broad leaf vegetation sampling of at least three different kinds of vegetation may be performed at the site boundary in each of two differer,t direction sectors with the highest predicted D/Qs in lieu cf the garden census.

Specifications

(

for broad leaf vegetation sampling in Table 3.12.1-1, 4c shall b3 followed.

including analysis of control samples.

APR 2 61985 RIVER BEND - UNIT 1 3/4 12-13

INSTRUMENTATION BASES

(

3/4.3.4 RECIRCULATION PUMP ' RID ACE." *:3N INSTRUPENTAT]ON The anticipated transient without scram (ATVS) recirculation pump trip system provides a means of limiting the consequences of the unlikely occurrence of a failure to scram during an anticipated transient.

The response of the plant to this postulated event falls within the envelope of study events in General Electric Company Topical Report NEDO-10349, dated March 1971 and NEDO-24222, dated December 1979, and Section 15.9 of the FSAR.

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

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

The physical phenomenaa 1.voived is

~

that the void reactivity feedback due to a pressurization transient can add positive reactivity to the reactor system at a faster rate than the control

~-

rods add negative scram reactivity.

Each EOC-RPT system trips both recircu-the core during two of the most limiting pressurization events.la The two events for which the EOC-RPT protective feature will function are closure of the turbine stop valves and fast closure of the turbine control valves.

A fast closure sensor from each of two turbine control valves provides C\\.

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

a position switch for each of two turbine stop valves provides input to oneSimilarly, EOC-RPT system; a position switch from each of the other two stop valves provides input to the other EOC-RPT system.

For each EOC-RPT system, the sensor relay contacts are arranged to form a 2-out-of-2 logic for the fast closure of turbine control valves and a 2 out-of-2 logic for the turbine stop vaTves.

trip both recirculation pumps.The operation of either logic will actuate the E Each EOC-RPT system may be manually bypassed by use of a keyswi dministratively controlled.

ch The manual bypasses and the automat ating ss at less than 40% of RATED THERMAL POWER are annunciated in th rol m.

between initiation of valve motion and eseplete suppThe EOC-R f the electric arc, i.e., 140 ms.

Included in this t w are: the espo me of the sensor, the time allotted for breaker arc suppression and t system logic.

e time of the within its specified Allowable Value is acceptable on the bas difference betweet, each Trip Setpoint and the Allowable Value is equal to or less than the drif t allowance assumec for each trip in the safety analyses.

RIVER BEND - UNIT 1 APR 2 61985 E 3/4 3-3

NOTE: SCALE IN INCHES ASC ' VESSEL ZERO CATL LEVEL NOMENCLATURE HEl2NT ASOVE N D.

VESSEL ZER3 (IN.)

READING

\\

300 (s)

C 572.su

+52

/

(7) sse.42

+3a.s

\\

i (4) 551.42

+30.s 750 -

(3) 529.52

+ 8.9 72L75 VESSEL _

(2 475.12 45.5 i

FLANGE 700 -

375.12' 145.5 650 -

MAIN

- 536.5-STEAM LINE INSTRUMENT ZERO g

M".--3rr" 572.82(Ph 2

8W 52(8)

[,33,g 52 TRIP RPS'(8) r= = =1.42(4)

MPCS. RCIC Hi ALARM

.= m e SOTTOM OF STEAM 550 -

55 TRIPS (4) ".30.8 LO CRYER SKIRT

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AM 8.9(3)

N505.82

- 520.52 0

0

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FEED 483.5500 0-REACTOR SCRAh WATER

- 475.12(2) CORE

-45.5(2)

CONFIRMATORY

-465 SPRAY ADS TRIP INITIATE RCIC, HPCS; p_

TRIP RECIRC. PUMPS g

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450 - -

408.56 400 - -

zy J.r42 350-35 5 INITI E RHR AND LPCS,

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START DIESEL, INITIATE ADS AND CLOSE MSIV'S g In ACTIVE i

FUEL 250 - -

U 208.56 200 = 206.56 g

-. / RECIRC

- 171.59 NLET OUTLET 186.5 NOZZLE

' 7 NOZZLE 150 - -

100 - -

)I 50 - -

Bases Figure 8 3/4 3-1 REACTOR VESSEL WATER LEVEL

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RIVER BEND - UNIT 1 8 3/4 3-8 2 6 1985 i

flNAI. Bya; RADIOLOGICAL ENVIRONMENTAL MONITORING BASES i

s 3/4/12.2 LAND USE CENSUS f

is specification is provided to ensure that changes in the use of areas l JM a

beyond the SITE BOUNDARY are identified and that modifications to the o ogical environmental monitoring program are made if required by the ra results of this census.

The best information from the door-to-door survey, from aerial survey or from consulting with local agricultural authorities shall be used. This census satisfies the requirements of Section IV.B.3 of Appendix I to 10 CFR Part 50.

Restricting the census to gardens of greater than 50 m2 provides assurance that significant exposure pathways via leafy vegetables will be identified and monitored since a garden of this size is the minimum required to produce the quantity (26 kg/ year) of leafy vegetables assumed in Regulatory Guide 1.109 for consumption by a child.

To determine this minimum garden size, the following assumptions were made:

1) 20% of the garden was used for growing broad leaf vegetation (i.e., similar to lettuce and cabbage), and 2) a vegetation yield of 2 kg/m,

2 3/4.12/3 INTERLAB'ORATORYCOMPARISONPROGkg g

The requirement for participation in c.n approved Interlaboratory Comparison Program is provided to ensure that independent checks on the precision and accuracy of the measurements of radioactive material in environmental sample matrices are performed as part of the quality assurance program for environment

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monitoring in order to demonstrate that the results are valid for the purposes of Section IV.B.2 of Appendix I to 10 CFR Part 50.

s APR 2 e 1995 RIVER BEND - UNIT 1 8 3/4 12-2

.. o s

Errors of Comission

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_ ELECTRICAL POWER SYSTEMS

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SURVEILLANCE REQUIREMENTS (Continued) 3.

Verifying the diesel generator capability to reject a load of 3130 kw for diesel generators 1A and 18 and 2600 kw for diese generator C without tripping.

The generator voltage shall not exceed 4784 volts for diesel generators 1A and 1B or 5824 volts for diesel generator IC during and following the load rejection 4

Simulating a loss of offsite power by itself, and:

a)

For divisions I and II:

1)

Verifying deenergization of the emergency busses and load shedding from the emergency busses.

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2)

Verifying the diesel generator starts on the auto start signal, energizes the emergency busses.with perm connected loads within 10 seconds, energizes the, auto-connected d utft:-

and operates for greater than or equal to 5 minu while its generator is loaded with the e _td r After energization, the steady state voltage and loads.

frequency of the emergency busses shall be maintained at 4160 2 420 I

volts and 60 2 3 Hz during this test.

LN b)

For division III:

1)

Verifying de energization of the emergency bus.

2)

Verifying the diesel generator starts on the auto-start signal, energizes the a yeny with the permanently greater than or equal (w0+secondsja operates for m

connected loads withi

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is loaded with the 9 + 5 - loads..- while its generator After energization j

bus shall be maintained atthe steady state voltage and 4160 2 420 volts and 60 2 M Hz during this test.

3 l

5.

Verifying that on an ECCS actuation test signal, without loss i

of offsite power, the diesel generator starts on the auto-start signal and operates on standby for greater than or equal to 5 minutes.

The generator voltage and frequency shall be 4160 2 420 volts and 60 2 3 Hz within 10 seconds after the au signal; the steady state generator voltage and frequency shall be maintained within these limits during this test.

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f RIVER BENO - UNIT 1 3/4 8-5 APR 2 61985

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SURVEILLANCE REQUIREMENTS (Continued) t t

=

6.

Simulating a loss of offsite power in conjunction with an ECCS actuation test signal, and:

a)

For divisions I and II:

1)

Verifying deenergization of the emeYgiincy busses and load shedding from the emergency busses.

2)

Verifying the diesel generator starts on the auto-start signal, energizes the emergency busses with permanently connected loads within 10 seconds, energizes the auto-connected Otutd; i. loads through the &oed sequencing logic and operates for greater than or equal to 5 minutes while_its generator is loaded with the emergency loads.

Af ter energiziation, the steady. state voltage and frequency of the emergency busses shAl be maintained at 4160 1 420 volts and 6013 Hz during this test.

b)

For division III:

• J

,3; 1)

Verifying de energization of the emergency bus.

2) pe-ash

~~+*A Verifying the diesel generator starts on the auto-start signal, energizes the emergency bus with its 1,.Jr w. +l.~ to sm/5----y E d: ;c.,: the auto connected r;;;n;y loads uittin ca e q.~e s 10 terrrd: and optrates for greater than or equal to

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5 cainutes while its generator is loaded with the emergency loads.

j Af ter energization, the. steady state h /WW7 voltage and frequency of the emergency bus shall be maintained at 4160 1 420 g,pglgDAW/

this test.

volts and 6013 Hz during 7.

Verifying that all automatic diesel generator trips are automatic-ally bypassed upon ECC ctuation signal except:

E 1

a)

For division differential engine overspeed and generator n

rren.

b)

For divisi n engine overspeed and generator differential current.

8.

Verifying the diesel generator operates for at least 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

The diesel generators shall be loaded to 3130 kw for diesel generator 1A and 18 and 2600 kw'for diesel generator IC.

The generator voltage and frequency shall be 4160 1 420 volts and 60 2 3 Hz within 10 seconds after the start signal; the steady

(

RIVER BEND - UNIT 1 3/4 8-6 APR 2 619B'

)

FROM ATTACHMENT B TO GSU LETTER OF MAY 6, 1985.

TECHNICAL CHANGE REOUESTS DESCRIPTION OF CHANGE / JUSTIFICATION:

28)TS 3.7.6.2 - Deleted Railroad Bay.

No sprinkler systems are identified for the railroad bay as there is no safety related equipment located in this area.

9 29) TS 4.7.6.3.a - Delete, g

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There are no valves in the flow path of any PGCC subsystem.

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% 30) TS 3/4.7.6 Table 3.7.6 1 - Added footnote *.

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Reflects River Bend design'.

31) TS Table 3.'7.8 Add items and revise temperatures.

Additional item have been identified for inclusion and corrections to temperatures from review of Environmental Desig.n Criteria.

32) TS 3/4.7.10 Added Table 3.7.10-2, revised the Technical Specification accordingly and also revised Table 3.7.10-1.

These changes make the Technical Specification consistent with FSAR Section 2.5.

33) TS 3/4.7.11 - Add new Specification.

This Specification is provided to address SER requirement in 9.1.3 page 9-6.

34) TS 3/4.8.1, 3.8.1.1 Action c,

4.8.1.1.2.f.4.b.2, 4.8.1.1.2.f.6.b.2, 3.8.1.2 Action b,

3.8.2.1 Action b, 3.8.2.2 Action b, and 3.8.3.1 Action b.2, - Addition of C SSW pump.

Revisions reflect the powering of standby service water pump ISWP*P2C and it's auxiliaries from the HPCS diesel (Div III).

35) TS 3.8.3.1.b.1 and 3.8.3.2.b.2 - Added panel IENB*PNLO4A.

Added in conjunction of outstanding SER open item 13, Safe / Alternate Shutdown Design Modification.

Page 6 of 7

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Edward J. Butcher May 17, 1985 same submittal, GSU properly proposed an identical change with the clause to be inserted after 10 seconds. As proposed on 3/4 8-5, the revision makes no sense and would confyse the operator.

(2) In Attachment B of the GSU submittal of May 6,1985, Item 29 -

requests a deletion of a surveillance requirement because -

i "There are no valves in the flow path of any PGCC subsystem."

i In past discussions, GSU has resisted this requirement on the 1

basis that the_ valves did not have a position indicator -

although, in fact, the valves do have a trip indicator.

A copy of FSAR Figure 9.5-13 is enclosed which shows numerous solenoid operated valves as well as a couple of check valves

)

in the flow path. Therefore,.the GSU statement of "no valves

)

in the flow path" appears to be a false representation.

i (3) Also, in Attachment 8, Item 30 refers to adding a footnote to TS 3/4.7.6.4, Table 3.7.6.4-1.

This is in error as the proposed footnote was identified with TS 3/4.7.6.5, Table 3.7.6.5-1.

In addition to the deficiencies noted above, I would like to coment briefly on other uncertainties associated with the River Bend Tech Spec review.

GSU has submitted a listing of 55 areas in the FSAR that need revision to support Tech Spec sections. Amendment 19 to the FSAR was delivered on May 14, 1985 and only 12 of these areas were addressed. Therefore, in the other 43 areas, the NRR Technical Reviewer has not seen the necessary documentation to support the current Tech Spec section or a proposed revision to a section. There is also the potential for additional FSAR revisions resulting from the reviewer's evaluation. This lack of timely information will impact the accelerated schedule for issuance of the Tech Specs with the River Bend license in June,1985.

There seem to be some values in the FSAR and Tech Specs that are constantly being changed. For example, the DBA activity release to the environment following a LOCA (used for containment Tech Spec review) were revised in Amendment 18 to the FSAR dated April 1985 and revised again (increased) in Amendment 19 on May 13, 1985.

In the-Tech Specs, GSU has pro the water level for-the Ultimate Heat Sink be 112'4" (2nd Draft) posed that -

, 108"6" (Final Draft) and 111'10" (current revision). Changes of this frequency would indicate that the utilities' review process has not settled down.

All of the above matters should be given due considerations when discussing commitments and completion schedules for the River Bend Tech Specs.

Original signed by M. Dean Houston, Reactor Engineer Technical Specification Review Group.

M Division of Licensing cc:

D. Crutchfield TSRG:DL Distribution R. Benedict DHouston jc Docket File "TSRG File S. Stern 5//p/85 -

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