Text

Forwards marked-up Tech Specs Changed Since .Tech Specs Accurately Reflect Design & Operating Program Described in FSAR
	ML20091Q981
Person / Time
Site:	Callaway
Issue date:	06/11/1984
From:	Schnell D; UNION ELECTRIC CO.
To:	Harold Denton; Office of Nuclear Reactor Regulation
References
	ULNRC-842, NUDOCS 8406140221
	Download: ML20091Q981 (21)
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UNION ' ELECTRIC COM PANY 5 908 GRATIOT STREET ST. LoulS, MISSOURI MAILING ADDRESS:

June 11, 1984'

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vfce passectest ST. LOUIS, MISSOUR8 83 5 66 Mr. Harold R.

Denton Office of Nuclear Reactor Regulation U.

S. Nuclear Regulatory Commission

. Washington,~ DC 20555; o

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Dear Mr. Denton:

ULNRC-84 2 DOCKET NUMBER 50-483 CALLAWAY PLANT, UNIT 1 CALLAWAY TECHNICAL SPECIFICATIONS

References:

. J)

ULNRC-792 dated April 9, 1984 2)

ULNRC-816 dated May ll, 1984 3)

ULNRC-835 dated May 31, 1984

Attachment:

Specifications-Changed Since Reference 3 In'the referenced letters Un' ion. Electric affirmed the

' accuracy of Callaway Technical Specifications.

The attachment to

.this letter contains specifications which have changed since Reference 3 and.which have M en resolved be+veen " ion Electric and the Staff,

-In my-judgement, the Cal!1away'Tr*

opecifications accurately reflect the plant desig'

. rating. program as described in the FSAR and other ini

n on our docket.

Very truly yours,-

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'd' Donald F.

Schnell DS/msc Attachment' c

cc:

J. Holonich' K

F.' Anderson F

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8406140221 G40611 PDR ADOCK 050004G3i-t

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STATE OF MISSOURI )

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SS CITY OF ST. Louis )

Donald F. Schnell, of lawful age, being first duly sworn

-upon oath says that he is Vice President-Nuclear and an officer of Union Electric Company; that he has read the foregoing document and knows the-c'ntent thereof; that he has executed the same for and on o

behalf of said company with full power and authority to do so; and that the facts,therein stated are true and correct to the best of his

.t knowledge,iinformation and belief.

By DUriald Fr Schnell Vice President Nuclear SUBSCRIBED and sworn to before me this //d day of 198d Q gp BARBARA J. PFAF[

).

. NOTARY PUBUC STATE OF MISSOURI i

MY COMMISSION EXPIRES APRIL 22,1965 ST. LOUIS COUNTY i!-

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cc:

Gerald Charnoff, Esq.

Shaw, Pittman, Potts & Trowbridge 1800 ' M. Street, N.W.

Washington, D.C.

20036 Nicholas A. Petrick Executive Director SNUPPS 5 Choke Cherry Road Rockville, Maryland 20850 John H. Neisler Callaway Resident Office

- U.S. Nuclear Regulatory Commission RR$1

-Steedman, Missouri _ 65077 William Forney Division of Projects and-Resident Programs, Chief, Section lA U.S. Nuclear Regulatory Commission-Region III 799-Roosevelt Road Glen Ellyn, Illinois 60137 Bruce Little Callaway Resident Office U.S. Nuclear Regulatory Commission PRil' Steedman, Missouri 65077

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SPECIFICATIONS CHANGED SINCE REFERENCE 3 INDEX Item.

Page

Agree.

Open Issue 1

3/4 1-10 X

Action Statement 2

3/4 3-19 X

Mode Applicability.

3

~3/4 3-37 X

' Mode Applicability 4-3/4 3-59

-X Typo 5

3/4 4-10 X

Editorial 6

3/4 6-5 X

Editorial 7

3/4 7-19'thru-23 X

Moved Part of Bases to LCO 8

3/4 7-36

-X Clarification of

~

Surveillance 9

3/4 9-6 X

Change in Limits 10 3/4 9-7 X

Change in Surveillance 11 B'3/4 4-1 X

Make Consistent with Spec. 3.4.1.2 12 B 3/4 7-5 X

Moved Part of Bases to LCO 13 6-4 X

Organization Change h

Pages are attached I.

+

REACTIVITY CONTROL SYSTEMS CHAkOING PUMPS - OPERATING

.(.

LIMITING CONDITION FOR OPERATION 3.1.2.4 At least two centrifugal charging pumps shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3.*

ACTION:

With only one centrifugal charging pump OPERABLE, restore at least two centrif-ugal charging pumps to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in at least HOT STANDBY and borated to a SHUTDOWN MARGIN equivalent to at least 1% ak/k at 200 F within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; restore at least two. charging pumps.to 0PERABLE status within the next 7 days or be in' HOT SHUTDOWN within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

1 k

j SURVEILLANCE REQUIREMENTS s 4.1.2.4 At least two centrifugal charging pumps shall be demonstrated OPERABLE by verifying, on recirculation flow, that the pump develops a differential pressure of greater than or equal to 2400 psid when tested pursuant to Specification 4.0.5.

i.

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I.

The provisions of Specifications 3.0.4 and 4.0.4 are not appl.icable for entry into MODE 3 for the centrifugal charging pump declared inoperable pursuant to Specification 4.1.2.3.2 provided that the centrifugal charging pump is restored to OPERABLE status within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months prior to the temperature of one or more of the RCS cold legs exceeding 375*F.

i CALLAWAY - UNIT 1 3/4 1-10

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TABLE 3."

(Crntinued)

ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION 9

r-h MINIMUM R-TOTAL NO.

CHANNELS CHANNELS APPLICABLE FUt'CTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION

.b 8.

Loss of Power a.

4 kV Bus Undervoltage 4/ Bus 2/ Bus 3/ Bus 1,2,3,4 19*

[

' -Loss of Voltage b.

4 kV Bus Undervoltage 4/ Bus

.2/ Bus 3/ Bus 1, 2, 3, 4 19*

-Grid Degraded Voltage 9.

Control Room Isolation a.

Manual Initiation 2

1 2.

..'All' 26

[,1,2,3,4 26 b.

Automatic Actuation 2

1 2

w}

Logic and Actuation

/j Relays (SSPS) y c.

Automatic Actuation Logic and Actuation Relays (BOP ESFAS) 2 l'

2 All 26 d.

Phase "A" Isolation See Item 3.a. above for all Phase "A" Isolation initiating functions and requirements.

10.

Solid-State Load Sequencer 2-1/ Train 1/ Train 2-1/ Train 1,2,3,4 25 11.

Engineered Safety Features Actuation System Interlocks a.

Pressurizer Pressure, 3

2

2 1,2,3 20 P-11 b.

Reactor Trip, P-4 4-2/ Train 2/ Train 2/ Train 1,2,3 22 4e

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TABLE 4.3-2 (Continued) 9

[:

ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION SURVEILLANCEREQbIREMENTS

_c TRIP E

ANALOG ACTUATING MODES Z

CHANNEL DEVICE.

MASTER SLAVE FOR WHICH g

CHANNEL CHANNEL OPERATIONAL 0PERATIONAL ACTUATION RELAY RELAY SURVEILLAP FUNCTIONAL _ UNIT CHECK CALIBRATION TEST TEST LOGIC TEST TEST TEST IS~REQUIRI 9.

Control Room Isolation a.

Manual Initiation N.A.

N.A.

'R N.A.

N.A.

All r %

b.

Automatic Actuation N.A.

N.A.

M(1)

Q(3)

' 1, 2, 3, J Logic and Actuation

~'

Relays (SSPS) c.

Automatic Actuation R'

Logic and Actuation Relays (BOP ESFAS)

N.A.

M(1)(2)

N.A.

All

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tj d.

Phase "A" Isolation See Item 3.a. above for all Phase "A" Isolation Surveillance Requirements.

10.

Solid-State Load Sequencer N.A.

N.A.

.M(1)(2)

N.A.

1,2,3,4 11.

Engineered Safety Features Actuation System Interlocks a.

Pressurizer Pressure, N.A.

R M

N.A.

1,2,3 P-11 b.

Reactor Trip, P-4 N.A.

N.A.

R N.A.

-N.A.

N.A.

1,2,3 TABLE NOTATIONS (1) Each train shall be tested at least every 62 days on a STAGGERED TEST BASIS.

(2) Continuity check may be excluded from the ACTUATION LOGIC TEST.

(3) Except Relays K602, K620, K622, K624, K630, K740, and K741, which shall be tested at least once per 18 months during refueling and during each COLD SHUTDOWN exceeding 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months unless they have been tested within the previous 90 days.

TABLE 3.3-11 (Continued)

FIRE DETECTION INSTRUMENTS TOTAL NUMBER-0F INSTRUMENTS

INSTRUMENT LOCATION ZONE HEAT FLAME SM0KE (x/y)

(x/y)

(x/y) 1406-Comp. Co'ol.'P'mp.-& Ht. Exch. A.

104 0/1 1406. Comp. Cool. Pmp. & Ht. Exch. A 118 2/0

1408-Aux. Bldg. 2026' Corridor #2 104

-0/9 1408-Aux. Bldg. 2026' Corridor #2 118 5/0 0/4((1)

'1409-Elec. Pene. Rm. B 106 1) 1409-Elec.-Pene. Rm. B 113 0/4

.1410-Elec..Pene. Rm. A 107 0/8(1) 1410-Elec. Pene. Rm. A 114 0/8(1) 1413-Aux. Shutdown Pnl. Rm.

118 4/0 1501-Ctr1. Rm. A/C & Filt. Units B.

110 10/0 1504-Ctmt. Purge Exh. & Mech. Equip. B 108 18/0 1506-Ctmt. Purge'Sup. AHU Rm. A 109 18/0 1507-Personnel Hatch Area 108 3/0 1509-Main Steam Iso. Valve.Rm. #2 115 1/)(- O 1508-Main-Steam Iso. Valve Rm. #1 115 1/,(- O

'1512-Ctrl. Rm. A/C & Filt. Units A 110 10/0 1513-Ctri. Bldg. Vent Sup. A/C Unit Rm.

109 3/0 Aux.-81dg. Duct 2047'6" 119 1/0 Containment **

201 1/0( )

Containment **

202 2/0(2) 1/0(2) 2)

-Containment **

'203 1/0(2)

. Containment **

204 3/0(2)

Con ta ir..nent**

206 1/0(

Containment **

215 Containment **

216 1/0(2) 2)

-1/0(2)

Containment **

217 1/0(

Containment **

218 Containment **

219 4/0 Containment ** i 220 1/0(2) 3101-Ctrl. Bldg. 1974' Pipe Space 300 11/0 3105-Ctr1. Bldg. Elec. Chase S. 1974' 300 1/0 3106-Ctri. Bldg. Elec. Chase N. 1974' 300 1/0 L

-Area Above Access Control 301 12/0 f.

3229-Ctri. Bldg. Elec. Chase S. 1984' 300 1/0 3230-Ctr1. Bldg. Elec. Chase N. 1984' 300 1/0 3301-ESF Swgr. Rm. #1-314 0/7(1) 0/7(1) 1)

3301-ESF Swgr. Rm. #1 315 0/5(

3302-ESF Swgr. Rm. #2 316 3302-ESF Swgr. Rm. #2 317 0/5(1) 3305-Ctrl. Bldg. Elec. Chase S. 2000' 301 1/0 3306-Ctri. Bldg. Elec. Chase N. 2000' 301

'1/0 3403-Non-Vit. Swgr. & Xfmr. Rm.-#1 304 0/1 3403-Non-Vit. Swgr. & Xfmr. Rm. #1 305 0/1(1) 3404-Switchboard Rm. #4 321 0/2 3404-Switchboard Rm. #4 322 0/2(1) 3405-Battery Rm. #4 303 2/0 3407-Battery Rm. #1 303 2/0 CALLAWAY'- UNIT 1 3/4 3-59

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-REACTOR COOLANT SYSTEti 3/4.4.4 RELIEF VALVES

(.

LIMITING CONDITION FOR OPERATION 3.4.4 All power-operated relief valves (PORVs) and their associated block valve:> shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.*

ACTION:

a.

With one or more PORV(s) inoperable because of excessive seat leakage, within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months either restore the PORV(s) to OPERABLE status or close the associated block _ valve (s); otherwise, be in at least HOT aTANDBY within$the' rim 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ' and in COLD SHUTDOWN within the folk sing i

30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

d b.

With one PORV inoperable due to causes other than excessive seat leakage, within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months either restore the PORV to OPERABLE status, or close the associated block valve and remove power from the block valve; restore the PORV to OPERABLE status within the following 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

c.

With both PORV(s) inoperable due to causes other than excessive seat g

leakage, within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months either restore each of the PORV(s) to OPERABLE status or close their associated block valve (s) and remove power from the block valve (s).and be in HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

d.

With one or more block valve (s) inoperable, within 1 hour:

(1) restore the block valve (s) to OPERABLE status, or close the block valve (s) and i

re:aove power from the block valve (s), or close the PORV and remove power from its associated solenoid valve; and (2) apply ACTION b. or l-

c. above. as appropriate, for the isolated PORV(s).

E.

The provisions of Specification 3.0.4 are not applicable.

SURVEILLANCE REQUIREMENTS l

+

4.4.4.1 In addition to the requirements of Specification 4.0.5, each PORV shall be demonstrated OPERABLE at least once per 18 months by performance of a CHANNEL CALIBRATION.

4.4.4.2 Each block valve shall be demonstrated OPERABLE at least once per 92 days by operating the valve through one. complete cycle of full travel unless

-the block valve is closed with power removed in order to meet the requirements l_

of ACTION b. or c. in Specification 3.4.4.

(

With all RCS cold leg temperatures above 368*F.

CALLAWAY - UNIT 1 3/4 4-10 l

1

CONTAINMENT SYSTEMS SURVEILLANCE REQUIREMENTS 4.6.1.3 Each containment air lock shall be demonstrated OPERABLE:

Within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months following each closing, except when the air lock is a.

being used for multiple entries, then at least once per 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , by verifying that the seal leakage is less than 0.005 L, as determined by precision flow measurements when measured for at least 30 seconds ~

nL be w the seals at a constant pressure o b.

By conducting overall air lock le skage tests at not less than P '

a 48 psig, and verifying the overa'.1 air lock leakage rate ic within

-its limit:

1)

At least once per 6 months,# and 2)

Prior to establishing CONTAINMENT INTEGRITY when maintenance has been performed on the air lock that could affect the air lock sealing capability.*

At least once per 6 months by verifying that only one door in each c.

air lock can be opened at a time.

~

f

The provisions of Specification 4.0.2 are not applicable.

This represents an exemption to Appendix J of 10 CFR Part 50.

CALLAWAY - UNIT 1 3/4 6-5

PLANT SYSTEMS 3/4.7.8 SNUBBERS LIMITING CONDITION FOR OPERATION 3.7.8 All snubbers shall.be OPERABLE. The only snubbers excluded from the requirement are those installed on nonsafety related systems and then only if their failure or failure of the system on which they are installed would have no adverse effect on any safety-related system.

APPLICABILITY:

MODES 1, 2, 3, and 4.

MODES 5 and 6 for snubbers located on

- systems required OPERABLE in those MODES.

ACTION:

With one or more snubbers inoperable on any system, within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months replace or restore the inoperable snubber (s) to OPERABLE status and perform an engineering evaluation per Specification 4.7.8g. on the attached component or declare the attached system inoperable and follow the appropriate ACTION statement for that. system.

SURVEILLANCE REQUIREMENTS 4.7.8 'Each snubber shall be demonstrated OPERABLE by performance of the

- following augmented inservice inspection program in lieu of the requirements of Specification 4.0.5.

a.

Inspection Types As used in this specification, type of snubber shall mean snubbers of the same design and manufacturer, irrespective of capacity.

b.

Visual Inspections Snuhbers are categorized as inaccessible or accessible during reactor operation.

Each of these groups (inaccessible and accessible) may be inspected independently according to the schedule below.

The first inservice visual inspection of each type of snubbers shall be performed after 4 months but within 10 months of commencing POWER OPERATI0i and shall include all hydraulic and mechanical snubbers.

If all snutbers of each type on any system are found OPERABLE during the first inservice visual inspection, the second inservice visual inspection of that system shall be performed at the first refueling outage.

Otherwise, subsequent visual inspections of a given system shall be performed in accordance with the following schedule:

4 CALLAWAY - UNIT 1 3/4 7-19

PLANT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued)

No. Inoperable Snubbers of Each Type Subsequent Visual on Any System per Inspection Period Inspection Period *#

0 18 months i 25%

1 12 months i 25%

2 6 months i 25%

3,4 124 days i 25%

5,6,7 62 days i 25%

8 or more 31 days i 25%

c.

Visual Inspection Acceptance Criteria f

Visual inspections shall verify:

(1) that there are no visible indications of damage or impaired OPERABILITY and (2) attachments to the foundation or supporting structure are secure, and (3) fasteners for attachment of the snubber to the component and to the snubber-anchorage are secure.

Snubbers which appear inoperable as a result of visual inspections may be determined OPERABLE for the purpose of establishing the next visual inspection interval, provided that:

(1) the cause of the rejection is clearly established and remedied for' that particular snubber and for other snubbers irrespective of type on that system that may be generically susceptible; or (2) the affected snubber is functionally tested in the as-found condition and determined OPERABLE per Specification 4.7.8f.

All snubbers connected to an inoperable common hydraulic fluid reservoir shall be counted as inoperable snubbers.

For those snubbers common to more than one system, the 0PERABILITY of such snubbers shall be considered in assessing the surveillance schedule for each of the related systems.

d.

Transient Event Inspection An insp tion shall be performed of all hydraulic and mechanical snubbers attached to sections of systems that have experienced unexpected, potentially damaging transients as determined from a l

review of operational data and a visual inspection of the systems

. within 6 months following such an event.

In addition to satisfy-l ing the visual inspection acceptance criteria, freedom-of-motion of l

mechanical snubbers shall be verified using at least one of the following:

(1) manually induced snubber movement; or (2) evaluation of in place snubber piston setting; or (3) stroking the mechanical snubber through its full range of travel.

l:

The inspection interval for each type of snubber on a given system shall not l

be lengthened more than one step at a time unless a generic problem has been identified and corrected; in that event the inspection interval may be length-ened one step the first time and two steps thereafter if no inoperable snubbers of that type are found on that system.

i

The provisions of Specification 4.0.2 are not applicable.

CALLAWAY - UNIT 1 3/4 7-20 t

PLANT SYSTEMS SURVEILLANCE' REQUIREMENTS (Continued) e.

-Functional Tests During the.first refueling shutdown and at least once per 18 months thereafter during shutdown, a representative sample of snubbers of each type shall be tested using one of the following sample plans.

The sample plan shall be selected prior to the test period and cannot be changed during the test period.

The NRC Regional Administrator shall be notified in writing of the sample plan selected for each snubber type prior to the test period or the sample plan used in the prior test period shall be implemented:

1)

A least 10% of the total of each type of snubber shall be functionally tested either in place or in a bench test.

For each snubber of a type that does not meet the functional test acceptance criteria of Specification 4.7.8f., an additional 10%

of that type of snubber shall be functionally tested until no more failures are found or until all snubbers of that type have been functionally tested; or 2)

A representative sample of each type of snubber shal be func-tionally tested in accordance with' Figure 4.7-1.

"C" is the total number of snubbers of a type found not meeting the accep-tance requirements of Specification 4.7.8f.

The cumulative number of snubbers of a type tested is denoted by "N".

At the end of each day's testing, the new value of "N" and "C" (pre-vious day's. total plus current day's increments) shall be plotted on Figure 4.7-1.

If at any time the point plotted falls in the " Reject" region, all snubbers of that type shall be functionally tested.

If at any time the point plotted falls in the " Accept" region, testing of that group of snubbers may be terminated. When the point plotted lies in the " Continue Testing" region, additional snubbers of that type shall be i

tested until the point falls in the " Accept" region or the

" Reject" region, or all the snubbers of that group have been tested.

Testing equipment failure during functional testing l

may invalidate that day's testing and allow that day's testing to resume anew at a later time provided all snubbers tested

!~

with the failed equipment during the day of equipment failure

-are retested; or l

3)

An initial representative sample of 55 snubbers shall be func-

-tionally tested.

For each snubber snubber type which does not L

meet the functional test acceptance criteria, another sample l

of at least one-half the size of the initial sample shall be tested until the total number tested is equal to the initial sample size multiplied by the factor, 1 + C/2, where "C" is the number of snubbers found which do not meet the functional test i-acceptance criteria.

The results from this sample plan shall be plotted using an " Accept" line which follows the equation N = 55(1 + C/2).

Each snubber point should be plotted as soon as the snubber is tested.

If the point plotted falls on or l-CALLAWAY - UNIT 1 3/4 7-21 o

l k-

PLANT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) below the " Accept" line, testing of that type of snubber may be terminated.

If the point plotted falls above the " Accept" line, testing must continue until the point falls in the " Accept" region or all the snubbers of that type have been tested.

The representative sample selected for the functional test sample plans shall be randomly selected from the snubbers of each type and reviewed before beginning the testing.

The review shall ensure, as far as practicable, that they are representative of the various con-figurations, operating environments, range of size, and capacity of snubbers of each type. Snubbers placed in the same location as snubbers which failed the previous functional test shall be retested at the time of the next functional test but shall not be included in the sample plan.

If during the functional testing, additional sampling is required due to failure of only one type of snubber, the functional test results shall be reviewed at that time to deter-mine if additional samples should be limited to the type of snubber which has failed the functional testing.

f.

Functional Test Acceptance Criteria The snubber functional test shall verify that:

1)

Activation (restraining action) is achieved within the specified range in both tension and compression; 2)

Snubber bleed, or release rate where required, is present in both tension and compression, within the specified range; and 3)

Where required, the force required to initiate or maintain motion of the snubber is within the specified range in both directions of travel.

Testing methods may be used to measure parameters indirectly or parameters other than those specified if those results can be correlated to the specified parameters through established methods.

g.

Service Life Monitoring Program An engineering evaluation shall be made of each failure to meet the fu.ictional test acceptance criteria to determine the cause of the failure.

The results of this evaluation shall be used, if applicable, in selecting snubbers to be tested in an effort to determine the OPERABILITY of other snubbers irrespective of type which may be subject to the same failure mode.

CALLAWAY - UNIT 1 3/4 7-22

PLANT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued)

For the snubbers found inoperable, an engineering evaluation shall be performed on the components to which the inoperable snubbers are attached.

The purpose of this engineering evaluation shall be to determine if the components to which the inoperable snubbers are attached were adversely affected by the inoperability of the snubbers in order to ensure that the component remains capable of meeting the designed service.

If any snubber selected for functional testing either fails to lock up or fails to. move, i.e., frozen-in place, the cause will he evaluated and, if caused by manufacturer or design deficiency, all snubbers of the same type subject to the same defect shall be func-tionally~ tested.

This testing requirement shall be independent of the requirements stated in Specification 4.7.8e. for snubbers not meeting the functional test acceptance criteria.

h.

Functional Testing of Repaired and Replaced Snubbers Snubbers which fail the visual inspection or the functional test acceptance criteria shall be repaired or replaced.

Repic_ement snubbers and snubbers which have repairs which might affect the functional test results shall be tested to meet the functional test criteria before installation in the unit.

Mechanical snubbers shall have met the acceptance criteria subsequent to their most recent service, and the freedom-of-motion test must have been performed within 12 months before being installed in the unit.

1.

Snubber Service Life Program The service life of hydraulic and mechanical snubbers shall be moni-tored to ensure that the service life is not exceeded between sur-veillance inspections.

The maximum expected service life for various seals, springs, and other critical parts shall be determined and established based on engineering information and shall be extended or shortened based on monitored test results and failure history.

Critical parts shall be replaced so that the maximum service life will not be exceeded during a period when the snubber is required to be OPERABLE.

The parts replacements shall be documented and the docu-mentation shall be retained in accordance with Specification 6.10.2.

CALLAWAY - UNIT 1 3/4 7-23

+

b-PLANT SYSTEMS I

3/4.7.11 FIRE BARRIER PENETRATIONS

(--

LIMITING CONDITION FOR OPERATION

-3.7.11 All fire barrier penetrations (walls, floor / ceilings, cable tray enclosures, and other fire barriers) separating safety related fire areas or separating portions of redundant systems important to safe shutdown within a fire area and all sealing devices in fire rated assembly penetrations (fire doors, fire windows, fire dampers, cable, piping, and ventilation duct

~

. penetration seals) shall be OPERABLE.

APPLICABILITY:

At all times.

' ACTION:

With one or more of the above required fire barrier penetrations a.

-inoperable, within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months establish a continuous fire watch on at least one side of the affected penetration, or verify the OPERABILITY of fire detectors on at least one side of the inoperable fire barrier and establish an hourly fire watch patrol.

E b.

.The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.

. SURVEILLANCE REQUIREMENTS - 4.7.11.1 At least once per 18 months the above required fire rated assemblies and penetration sealing devices shall be verified OPERABLE by performing a

. visual inspection of:

The exposed surfaces of-each fire rated assembly, l

a.

b.

Each fire window / fire damper and associated hardware, and At least 10% of each type (electrical and mechanical) of sealed pene-c.

tration.

If apparent changes in appearance or abnormal degradations are found, a visual inspection of an additional 10% of each type of sealed penetration shall be made.' This inspection process shall

-continue until'a 10%' sample with no apparent changes in appearance or abnormal degradation is found.

Samples shall be selected such that each penetration seal will be inspected every 15 years.

~ 4.7.11.2 Each of the above required fire doors shall be verified OPERABLE by inspecting the automatic hold-open, release and closing mechanism and latches at least once per 6 months, and by verifying:

The OPERABILITY of the Fire Door Supervision System for each electri-a.

cally supervised fire door by performing a TRIP ACTUATING DEVICE OPERATIONAL TEST at least once per 31 days, s

Thateachlockedclosedfire'dooriithoutelectricalsupervision_Js

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b.

closed at least once per 7 days, '

That doors with autcmatic hold-open and release mechanisms are free c.

l of obstructions at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months and performing a functional test at least once par 18 months, and I

That each unlocked fire door without electrical supervision is closed d.

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

CALLAWAY - UNIT 1 3/4 7-36 8

'*-1

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REFUELING OPERATIONS 3/4.9.6 REFUELING MACHINE-LIMITING CONDITION FOR OPERATION 3.9.6 The refueling machine shall be used for movement of drive rods or fuel

' assemblies and shall be OPERABLE with:

The refueling machine used for movement of fuel assemblies having:

a.

'1)

A minimum capacity of 4800 pounds,

'2)

Automatic overload cutoffs with the following Setpoints:

Primary - h than or equa1 7 250 poundp_aboyftthe indicated a) 9 Jyspndedweightforwetconditionsand(lessthanorequal to 3 pounds above the indicated suspended weight for dry

'cond ions, and

-b)

Secondary-(l'essthanorequalto]150poundsabovethe primary overload cutoff.

3)

Anautomaticload'reductiontripwithaSetpointofdessthan y equabto 250 pounds below the suspended weight for wet;or dry b.

The auxiriary hoist used for latching and unlatching drive rods and thimble plug handling operations having:

1)

A minimum capacity of 3000 pounds,-and 2)

A 1000 pound 11oad indicator which shall be used to monitor lifting loads for these operation.

APPLICABILITY: During movement of drive rods or fuel assemblies within the reactor vessel.

ACTION:

With the requirements for refueling machine and/or auxiliary hoist OPERABILITY not satisified, suspend use of any inoperable refueling machine crane and/or auxiliary hoist from operations involving the movement of drive rods and fuel assemblies within the reactor vessel.

SURVEILLANCE REQUIREMENTS 4.9.6.1 The refueling machine used for movement of fuel assemblies within the reactor vessel shall be demonstrated OPERABLE within 100 hours0.00116 days 0.0278 hours 1.653439e-4 weeks 3.805e-5 months prior CALLAWAY - UNIT 1 3/4 9-6

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-REFUELING OPERATIONS SURVEILLANCE REQUIREMENTS (Continued)

- to removal of the reactor vessel head by performing a load test of at least 125%

of the secondary _ automatic overload cutoff and demonstrating an automatic load cutoff whephe _refuelina machine load exceeds the Setpoints of Specification 3,9_6a. w_, and by demonstrating an automatic load reduction trip wnen the loa jeductionge Satpoint-of--Specifdcation.L9Ja.3).

4.9.6.2 Each auxiliary hoist and associated load indicator used for movement of drive rods within the reactor vessel shall be demonstrated OPERABLE within 100 hours0.00116 days 0.0278 hours 1.653439e-4 weeks 3.805e-5 months prior to removal of the reactor vessel head by performing a load test of at least 1250 pounds.

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3/4.4 REACTOR COOLANT SYSTEM

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BASES 3/4.4.1 REACTOR COOLANT LOOPS AND COOLANT CIRCULATION The plant is designed to operate with all reactor coolant loops in opera-tion and maintain DNBR above 1.30 during all normal operations and anticipated transients.

In MODES 1 and 2 with one reactor coolant loop not in operation this specification requires that the plant be in at least HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

~

N In MODE 3,1two leactor coolantj oops provide sufficient heat removal I

capability Jpr-removing decay heat; however, single failure considerations require that three loops be OPERABLE.

Q In MODE 4, and in MODE 5 with reactor coolant loops. filled, a single reactor coolant loop or RHR loop provides sufficient heat removal capability for removing decay heat; but single failure considerations require that at least two loops (either RHR or RCS) be OPERABLE.

In MODE 5 with reactor coolant loops not filled, a single RHR loop provides sufficient heat removal capability for removing decay heat; but single failure considerations, and the unavailability of the steam generators as a heat removing component, require that at least two RHR loops be OPERABLE.

(

The operation of one reactor coolant pump (RCP) or one RHR pump provides adequate flow to ensure mixing, prevent stratification and produce gradual reactivity changes during boron concentration reductions in the Reactor Coolant System.

The reactivity change rate associated with boron reduction will, therefore, be within the capability of operator recognition and control.

The restrictions on starting a reactor coolant pump in MODES 4 and 5 are provided to prevent RCS pressure transients, caused by energy additions

'from the Secondary Coolant System, which could exceed the limits of Appendix G to 10 CFR Part 50.

The RCS will be protected against overpretsure transients and will not exceed the limits of Appendix G by restricting starting of the Rrpe tn when the secondary Water temperature of each steam generator is less than 50 F above each of the RCS cold leg temperatures.

i e

1 CALLAWAY - UNIT 1 B 3/4 4-1

m n

PLAMT SYSTEMS BASES 3/4.7.8 ~ SNUBBERS All snubbers are required OPERABLE to ensure that the structural integrity iof the Reactor Coolant System and all other safety-related systems are main-tained during and following a seismic or other event initiating dynamic loads.

Snubbers are classified and grouped by design and manufacturer, but not by size.

For example, mechanical snubbers utilizing the same design features of the 2-kip,10-kip and 100-kip capacity manufactured by Company "A" are of the same type.

The same design mechanical snubbers manufactured by Company "B" for the purposes of this Technical Specification would be of a different type, as would hydraulic snubbers from either manufacturer.

Snubbers may also be classified and grouped by inaccessible or accessible for visual inspection purposes. -Therefore, each snubber type may be grouped for inspection in accordance with accessibility.

A list of individual snubbers with detailed information of snubber location and size and of' systems affected shall be available at the plant in accordance with Section 50.71(c) of 10 CFR Part 50.

The accessibility of each snubber shall be determined and approved by the On-Site Review Committee.

The deter-mination shall be based upon the existing radiation levels and the expected time to perform a visual inspection in each snubber location as well as other factors associated with accessibility during plant operations (e.g., tempera-ture, atmosphere, location etc.), and the recommendations of Regulatory Guides 8.8 and 8.10.

The addition or deletion of any hydraulic or mechanical snubber shall be made in accordance with Section 50.59 of 10 CFR Part 50.

The visual inspection frequency is based upon maintaining a constant level of snubber protection to each safety-related system during an earthquake or severe transient.

Therefore, the required inspection interval' varies inversely with the observed snubber failures on a given system and is determined by the number of inoperable snubbers found during an inspection of each system.

In order to establish the inspection frequency for each type of snubber on a safety related system, it was assumed that the frequency of snubber failures and initiating events is constant with time and that the failure of any snubber on that system could cause the system to be unprotected and to result in failure during an assumed initiating event.

Inspections performed before that interval has elapsed may be used as a new reference point to determine the

-next inspection.

However, the results of such early inspections performed before the original required time interval has elapsed (nominal time less 25%)

may not be used.to lengthen the required inspection interval.

Any inspection whose results require a shorter inspection interval will override the previous schedule.

The acceptance criteria are to be used in the visual inspection to deter-mine OPERABILITY of the snubbers.

For example, if a fluid port of a hydraulic CALLAWAY - UNIT 1 B 3/4 7-5

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ML20091Q981

Contents

Text

Dear Mr. Denton:

References:

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ML20091Q981

Text

Dear Mr. Denton:

References:

Attachment:

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