Text

Amends 109 & 92 to Licenses DPR-53 & DPR-69,respectively, Amending Tech Specs to Reflect Clarification of Surveillance Requirements of Tech Spec 4.6.1.6.2 Re Containment Tendon End Anchorages
	ML20138Q139
Person / Time
Site:	Calvert Cliffs
Issue date:	12/09/1985
From:	Thadani A; Office of Nuclear Reactor Regulation
To:	; Baltimore Gas & Electric Co (BGE)
Shared Package
ML20138Q143	List: ML20138Q139; ML20138Q168;
References
	DPR-53-A-109, DPR-69-A-092 NUDOCS 8512270067
	Download: ML20138Q139 (55)
	v • d • e

.__

\\

pMe%9k UNITED STATES g

NUCLEAR REGULATORY COMMISSION 5

E r

CASHINGTON, D. C. 20555 A...../

BALTIMORE GAS AND ELECTRIC COMPANY j

DOCKET NO. 50-317-i 1

CALVERT CLIFFS NUCLEAR POWER PLANT UNIT NO. 1 AMEN 0 MENT TO FACILITY OPERATING LICENSE Amendment No.109 License No. DPR-53 1.

The Nuclear Regulatory Connission (the Connission) has found that:

A.

The application for amendment by Baltimore Gas & Electric Company t

(the licensee) dated April 26, 1985 as supplemented by letter dated 4

September 30, 1985, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's rules and regulations set forth in 10 CFR Chapter I; 8.

The facility will operate in confonnity with the application, the provisions of the Act, and the rules and regulations of the Connission; C.

There is reasonable assurance (1) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commission's regulations; D.

The issuance of this amendment will not be inimical to the connon defense and security or to the health and safety of the public; and E.

The issuance of this amendment is in accordance with 10 CFR Part 51 of the Connission's regulations and all applicable requirements have been satisfied.

i 1

1 8512270067 851209 PDR ADOCK 05000317 P

PDR I

i b

i 1

~..

-... ~.

e

-_r.

,.m_..r_

..,_,_.,%,,....m..,r,.,.,__

2.

Accordingly, the license is amended by changes to the Technical Specifications as indicated in the attachment to this license amendment, and paragraph 2.C.(2) of Facility Operating License No. DPR-S3 is hereby amended to read as follows:

(2) Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No.109, are hereby incorporated in tha license. The licensee shall operate the facility in accordance with the Technical Specifications.

3.

This license amendment is effective as of the date of its issuance.

FOR TH NUCLEAR REGULATORY COMMISSION

'I N

Asho C. Thadani, Director PWR roject Directorate #8 j

Division of PWR Licensing-B

Attachment:

Changes to the Technical Specifications Date of Issuance: December 9, 1985

![

i t.

T i

l

ATTACHMENT TO LICENSE AMENDMENT NO. 109 FACILITY OPERATING LICENSE NO. DPR-53 DOCKET NO. 50-317 Replace the following pages of the Appendix "A" Technical Specifications with the enclosed pages. The revised pages are identified by amendment number and contain vertical lines indicating the areas of change. The corresponding overleaf pages are provided to maintain document completeness.

Remove Pages Insert Pages IV IV 3/4 3-26 3/4 3-26 3/4 3-28 3/4 3-28 3/3 3-45 3/4 3-45 3/4 3-46 3/4 3-46

'j 3/4 3-47 3/4 3-47 3/4 6-9 3/4 6-9 3/4 6-26 3/4 6-26 i

3/4 7-5 3/4 7-5 3/4 7-5b 3/4 7-Sb 3/4 8-3 3/4 8-3

s B 3/4 3-2 B 3/4 3-2 B 3/4 3-3 B 3/4 3-3 B 3/4 6-2 8 3/4 6-2 j

t i

I

__...,.,.-,,,___,.,r,.

i 6

'fNDEX LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REQUIREMENTS ^

SECTION PAGE 3/4.0 APPLICABILITY...........................................

3/4 0-1 3/4.1 REACTIVITY CONTROL SYSTEP6 3/4.1.1 BORATION CONTROL Shutdown Margia - T,yg > 200*F.......................

3/4 1-1 Shutdown Margin - T,yg < 200*F.......................

3/41-3

~

B o ro n D i l u t i o n...................................... 3/4 1-4 Moderator Temperature Coefficient................... 3/4 1-5 Minimum Temperature for Criticality..................

3/41-7 3/4.1.2 B0 RATION SYSTEMS Fl ow Pa ths - Shu tdown................................ 3/4 1-8 Flow Paths - Operating...............................

3/4 1-9 C harging Pump - S hu tdown............................. 3/4 1-10 Charging Pumps - Operating........................... 3/4 1-11 Boric Acid. Pumps - Shutdown.......................... 3/4 1-12 Boric Acid Pumps - Operating.........................

3/4 1 _13

Borated Water Sources - Shutdown.....................

3/4 1-14 Borated Water Sources - Operating.................... 3/4 1-16 3/4.1.3 MOVABLE CONTROL ASSEMBLIES Full Length CEA Position.............................

3/4 1-17 Position Indicator Channels..........................

3/4 1 - 21 CEA Drop Time........................................

3/4 1-23 Shutdown CEA Insertion Limi ts........................ 3/4 1-24 Regulating CEA insertion Limits......................

3/4 1-25 CALVERT CLIFFS - UNIT 1 III knendment No. 32 en o

e e

ee i

I I

INDEX u

LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REQUIREMENTS SECTION PAGE

' '4. 2 POWER DISTRIBUTION LIMITS i

3/4.2.1 LINEAR HEAT RATE...................................... 3/4 2-1 4

3/4.2.2 TOTAL PLANAR RADIAL PEAKING FACT 0R.................... 3/4 2-6 3/4.2.3 TOTAL INTEGRATED RADIAL FEAKING FACTOR................. 3/4 2-9 3/4.2.4 AZIMUTHAL POWER TILT.................................. 3/4 2-12 3/4.2.5 DNS PARAMETERS........................................

3/4 2-13 3/4.3 INSTRUMENTATION 3/4.3.1 REACTOR PROTECTIVE INSTRUMENTATION....................

3/4 3-1 3/4.3.2 ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION.....................................

3/4 3-10 3/4.3.3 MONITORING INSTRUMENTATION Radiation Moni toring Instrumentation.................. 3/4 3-25 Incore Detectors......................................

3/4 3-29 Seismic Instrumentation.............................. 3/4 3-31 Meteorological Instrumentation........................

3/4 3-34 Remote Shutdown Instrumentation........................ 3/4 3-37 Post Accident Instrumentation......................... 3/4 3-40 Fire Detection Instrumentation........................

3/4 3-43 l

Radioacttye Gaseous. Effluent Monitori.ng.

Instrumentation...............;......'.....c.........

3/4 3-48 l

l Radioactive Liquid Effluent Monitoring Instrumentation.....................................

3/4 3-53 3/4.4 REACTOR COOLANT SYSTEM 3/4.4.1 COOLANT LOOPS AND COOLANT CIRCULATION.................

3/4 4-1 Startup and Power.....................................

3/4 4-1 i

Hot Standby...........................................

3/4 4-2 i

Shutdown..............................................

3/4 4-2a 3/4.4.2 SAFETY VALVES.........................................

3/4 4-3 3/4.4.3 RELIEF VALVES.........................................

3/4 4-4 CALVERr CLIFFS - UNIT 1 IV AmendmentNo.3A.53.55.99./Itl9 109

' INSTRUMENTATION 3/4.3.3 MONITORING INSTRUMENTATION RADIATION MONITORING INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.3.1 The radiation monitoring instrumentation channels shown in Table 3.3-6 shall be OPERABLE with their alarm / trip setpoints within the specified limits.

APPLICABILITY: As shown in Table 3.3-6.

ACTION:

a.

With a radiation monitoring channel alann/ trip setpoint exceeding the value shown in Table 3.3-6, adjust the set-point to within the limit within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months or declare the channel inoperable.

b.

With one or more radiation monitoring channels inoperable, take the ACTION shown in Table 3.3-6.

c.

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

SURVEILLANCE REQUIREMENTS 4.3.3.1 Each radiation monitoring instrumentation channel shall be demonstrated OPERABLE by the performance of the CHANNEL CHECK CHANNEL CALIBRATION and CHANNEL FUNCTIONAL TEST operations during the modes

}

and at the frequencies shown in Table 4.3-3.

l CALVERT CLIFFS - UNIT 1 3/4~3 25 s

.. ~ ~ -

y..-.--.....-4-.-.-

-w.,--.s.

. -. --. -,--,,,,--e,-

,,.,,er,aw-,,,--*,---ww

,--w cr--,-newg-,-m,a~v-

--~,--o,em-v-ww,-

--,r-we

-,,w-s-w,,---ymw-

,,w.,-,e..g-w p

-me,,-

,~s-e m--n.e me.-

l

't i

e i

t l

TABLE 3.3-6 1

i RADIATION BOIITORING INSTRUMENTATION i

k

i MINIfRM 5

CHANNELS APPLICABLE ALARM / TRIP MEASUREMENT INSTIRRENT OPERABLE M00ES

_SETPOINT RANGE ACTION n

I C

a,

1. AREA MONITORS u

j

a. Containment E

1. Purge & Exhaust j

4 Isolation 3

6

=_ 220 mr/hr 10-j - 10 mr/hr 16 4

l

b. Containment Area High 8

j Range 2

1, 2, 3, & 4

< 10 R/hr 1 - 10 R/hr 30

2. PROCESS letITORS l

a. Containment w

5

1. Gaseous Activity i

w 1

A a)RCSLeakage 6

j Detection 1

1, 2. ?, & 4 Not Applicable 1 - 10 cpm 14

}

11. Particu'Inte Activity I

a)RCSLeakage 6

i Detection 1

1, 2.'3, & 4 Not Applicable 1 - 10 cpm 14

b. Effluent Monitors i

=

I

1. Main Vent Wide Range l

S a)llobleGas-

.1 1.2,3,&4 10-7 to 10+5 pCi/cc 30

)

.I b)IodineSampler 1

1, 2, 3, & 4 Not Applicable Not Applicable 30

,3 c)P9rticulateSampler 1

1, 2, 3, & 4 Not Applicable Not Applicable,

$ 30 3

Alarm setpoint to be specified in a controlled document (e.g., setroint control manual) l 4

l i

r TABLE 3.3-6 (Continued)

TABLE NOTATION ACTION 14 - With the number of channels OPERABLE less than required by the Minimum Channels OPERABLE requirement, comply with the ACTION requirements of Specification 3.4.6.1.

ACTION 16 - With the number of channels ~0PERABLE less than required by the Minimum Channels OPERABLE requirement, ccmply with the ACTION requirements of Specification 3.9.9.

ACTION 30 - With the number of channels OPERABLE less than required by the Minimum Channels OPERABLE requirement, initiate the preplanned alternate method of monitoring the appro-priate parameter (s), within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , and:

1) either restore the inoperable channel (s) to OPERABLE status within 7 days of the event, or 4

2) prepare and submit a Special Report to the Commission pursuant to Specificat'on 6.9.2 within 30 days follow-ing the event, outlining the action taken, the cause of the inoperability, tnd the plans and schedule for restoring the system to OPERABLE status.

CALVERT CLIFFS - UNIT 1 3/4 3-27 Amendment No. 99 e

i TABLE 4.3-3 RADIATION IENIITORING INSTRUENTATION SURVEILLANCE REQUIREMENTS g

Ni CHANNEL MODES IN WHICH E

CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE p

INSTRtN NT CHECK CALIBRATION TEST REQUIRED 3

1.

AREA MONITORS

[

a.

Contaitument 5

1.

Purge & Exhaust

[-

Isolation S

R M

6 b.

Containment Area High Range S

R M

1, 2, 3, & 4 g

2.

PROCESS MDNITORS y

a.

Containment E

1.

Gaseous Activity a) RCS Leakage Detection S

R M

1, 2, 3, & 4

11. Particulate Activity y

a) RCS Leakage g

Detection 5

R M

1, 2, 3, & 4 b.

Effluent Monitor 1.

Main Vent Wide Range

.I a) Noble Gas S

R M

1, 2, 3, & 4 g

b) Iodine Sampfer M*

Not Applicable Not Applicable 1, 2, 3, & 4 g

-(

c) Particulate Sampler M*

Not Applicable Not Applicable 1, 2, 3, & 4 E

The CHANNEL CHECK shall be accomplished by comparing samples independently drawn from the main vent.

G e

l

=

TABL53.3-11 FIRE DETECTION INSTRUMENTS UNIT 1 MINIMUM INS'iRUMENTS OPERABLE

ROOM / AREA AUX BLDG INSTRUMENT LOCATION HEAT FLAME SM0KE 100/103/

104/106 Corridors - Elev (-)10"-0" 5

110 Coolant Waste Rec & Mon. Tk Pp Rm 2

111 Waste Processing Control Rm 4

i 112/114 Coolant Waste Rec Tank 1

115 Charging Pump Room 3

118/122 ECCS Pump Roo.n 7

11S/123 ECCS Pump Room 7

200/202 Corridors, &

209/210 Corridors &

212/219 Corridors 13 207/208 Waste Gas Equip Rm 3

216 Reactor Coolant Make-up Pumps 1

217 Boric Acid Tank & Pump Room 2

218 Volume Control Tank Room 1

220 Degasifier Pump Room 1

221/326 West Piping Penetration. Room 2

3 222 Hot Instrument Shop 2

223 Hot Machine Shop 4

1 224 12 MSIY Hyd Area 10 l

225 Rad Exhaust Vent Equip Rm 4

l 226 Service Water Pump Rm 3

6 i

227/316-East. Piping Penetration Rm 3

5 i

228 Component Cooling Pump Rm 8

301/304/300 Battery Room & Corridor 3

306/1C Cable Spreading Rm & Cable Chase ** 2 10 l

308 N/S Corridor 6

l 315 Main Steam Piping Area 6

317 Switchgear Room. Elev 27'-0"**

6 318 Purge Air Supply Room 2

l 319/325 West Passage and Vestibule 6

l 320 Spent Fuel Heat Exchange Room 3

I 323 Passage 27' Valve Alley & Filter Rm 3

l 324 Letdown Heat Exchanger Rm 1

(

Elev. 27'-0" Switchgear Vent Duct 1

I 1A Cable Chase 1A 1

1B Cable Chase 1B 1

405 Control Room 6

410 N/S Corridor 4

417/418 Solid Waste Processing 2

3 l

CALVERT CLIFFS - UNIT 1 3/4 3-45 Amendment No. 26,87,86,109 0

,y m._._.__4.._-.-,,-_,,-yc._.-.

,,,w,y,

.,.-.,,n

,-- m

,.m..,7 m,,,,.,-.-y--,

w, r e m, n-.w.gy.,,mmm-w.,y,

-,-,-,,,w,,-,,,_,-,-,--,-ww.-w

TABLE 3.3-11 (Continued)

FIRE DETECTION INSTRUMENTS UNIT 1 MINIMUM INSTRUMENTS OPERABLE

ROOM / AREA AUX BLDG INSTRUMENT LOCATION HEAT FLAME SM0KE 413/419/420 Cask and Equip Loading Area &

424/425/426 Cask and Equip Loadin Area 3

22 4 21 Diesel Generator No.

12)**

2 422 Diesel Generator No.

11)**

2 423 West Electrical Pen Rm 3

428 East Piping Area 7

429 East Electrical Pene Rm 3

430.'

Switchgear Room Elev 45'-0"**

8

\\

439 Refueling Water Tank Pump Rm 2

e 441 Spent Resin Metering Tank Rm 1

Elev 45'-0" Switchgear Vent Duct 1

Elev 69'-0" Control Room Vent Duct "A" 1

Elev 69'-0" Cable Spreading Room Vent Duct 1

512 Control Room HVAC Equipment 4

~

586-590, Radiaticn Chemistry Area, 592,593 Radiation Chemistry Area, 595-597, Radiation Chemistry Area &

521.523 Corridors 20 520 Spent Fuel Pool Area Vent Equip Rm 2

524 Main Plant Exhaust Equip Rm 8

525 Cntat Access Area 3

529' Electrical Equip. Room 3

i,.

P 530/531/533 Spent Fuel Pool Area 5

17 3

536/537 Misc Waste Evaporator & Equip Rm 3

Elev 83'-0" Cable Tunnel 4

l4 603 Auxiliary Feedwater Pump Rm 2

Containment 81 dos U-1 RCP Bay East *

'16 U-1 RCP Bay West

16 i

U-1 East Electric Pen Area

4***

l U-1 West Electric Pen Area

4***

l Intake Structure Elev 3'-0" Unit 1 Side 24

Detection instruments located within the containment are not required to be OPERABLE during the performance of Type A Containment Leakage Rate Tests.

- Detectors which autos.atically actuate fire suppression systems.

- - Monitored by four protecto wires.

CALVERT CLIFFS - UNIT 1 3/4 3-46 Amendment No. 28,$J.95,109

8 1

a

.i A

l i

J J

t i

I J

i t

1 i

H IS PAGE INTENTIONALLY LEFT BLANK E

1 i

i 5

I 1i i

l d

i CALVERT CLIFFS - UNIT 1 3/4 3-47 Amendment No. 3), 109 b

- - _ _ _. _ _. _ -. _ _ _ _ _ _ _. _ _. - _ _.. _. _. _ _ _ _. _.. - _.. _ _ _.. _..,.. -.. _. _. ~. _ _ _. _.. _... _. _. - -........ _ _.... _

CONTAINMENT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued)

In addition, determining that the average of the normalized lif t-off forces for each sample population (hoop, vertical, dome) is equal to or greater than the required average prestress level; 536 kips for hoop tendons, 622 kips for vertical tendons, and 555 kips for dome tendons (reference Figures 4.6-1, -2, and -3).

If the average is below the required average prestress force, it shall be considered as evidence of possible abnonnal degradation of the containment structure.

b.

Removing one wire from each of a dome, vertical and hoop tendon checked for lift off force, and determining over the entire length of the wire:

1.

The extent of corrosion, cracks, or other damage. The presence of abnormal corrosion, cracks or other damage shall be considered evidence of possible abnonnal degradation of the containment structure.

2.

A minimum tensile strength value of 240 Ksi (guaranteed ultimate strength of the tendon material) for at least three wire samples (one from each end and one at mid-length) cut from each removed wire. Failure of any one of the wire samples to meet the minimum tensile strength test is evidence of possible abnormal degradation of the containment structure, Perform a chemical analysis to detect changes in the chemical properties c.

of the sheath filler grease. Any unusual changes in physical appearance or chemical properties that could adversely affect the ability of the filler grease to adhere to the tendon wires or otherwise inhibit corro-sion shall be reported to the Connission pursuant to Specification 6.9.2 within the next 30 days.

4.6.1.6.2 End Anchorages and Adjacent Concrete Surfaces. The structural integ-rity of the end anchorages and adjacent concrete surfaces shall be demonstrated by determining through inspection of a representative sample of tendons (refer-ence Specification 4.6.1.6.1) that no apparent changes have occurred in the visual appearance of the end anchorages or their adjacent concrete exterior i

surfaces. Also, inspections of the pre-selected concrete crack patterns adja-cent to end anchorages shall be perfonned during the Type A containment leakage

(

rate tests (reference Specification 4.6.1.2) while the containment is at its maximum test pressure.

^

4.6.1.6.3 Containment Surfaces. The exposed accessible interior and exterior j

surfaces of the containment, including the liner plate shall be vi,sually inspected during the shutdown for each Type A containment leakage rate test (reference Specification 4.6.1.2).

This inspection shall be performed prior to the Type A containment leakage rate test to uncover any evidence of j

structural deterioration which may affect either the containment structural, integrity or leak tightness.

4.6.1.6.4 Reports. Any abnormal degradation of the containment structure detected during the above required tests and inspections shall be reported to the Connission pursuant to Specification 6.9.2 within the next 30 days. This report shall include a description of the tendon condition, the condition of the c6ncrete (especially at tendon anchorages), the inspection procedures, the tolerances on cracking, and the corrective actions taken.

l l

CALVERT CLIFFS - IJNIT 1 3/4 6-9 Amendment No. 56.94, 109 t

" ~ ' * ~ ~ ~ ~ * * ' ~ ~

800 700 Expected t

67?

Lower Limit Expected Range 635 m.,

636 H

N

===, %

.k em m.

K

"'"=.m, I

f600

"""===. 600 i

Required Average

i 536 536

.}r f

N7 **"

t 500 lower Bound

= = =

Individual

~

==.m., % 482 t

i 1

10 40 100 Years Figure 4.61 Normalized Prestress Hoop Tendons CALVERT CLIFFS - U.':IT 1 3/4 6-9a Amendment No. 86 l

j e-1 l

i t

3:

f TABLE 3.6-1 (Continued) h CONTAINitENT ISOLATION VALVES l

M

' 4"l

'~

4 PENETRATION ISOLATION ISOLATION VALVE ISOLATION j

NO.

CHANNEL IDENTIFICATION NO.

FUNCTION TIME (SECONOS) n C

1 4

61 NA

$FP-176 Refueling Pool Outlet NA NA

-SFP-174 1

NA 1

NA SFP-172 NA I

E NA SFP-18g NA G

j 62 SIAS A PH-6579-MOV Containment Heating Outlet

<13

{

64 NA PH-376 Containment Heating Inlet NA j

i

{

g (1) Manual or remote manual valve which is closed during plant operation.

m j

(2) May be opened below 300*F to establish shutdown cooling flow.

m I

(3) Containment purge and containment vent isolation valves will be shut in MODES 1, 2, 3 and 4 i

per TS 3/4 6.1.7 and TS 3/4 6.1.8. respectively.

g j

May be open on an intermittent basis under administrative control.

,I l

- Containment purge isolation valves isolation times will only apply for MODES 5 and 6 during R

which time these valves may be opened.

Isolation time for containment purge and containment

-(

i g

vent isolation valves is MA for MODES 1, 2, 3 and 4 per TS 3/4 6.1.7 and TS 3/4 6.1.8, j

R respectively, during which time these valves must remain closed.

i e

e+

N A

k.

i

=

l i

CONTAINMENT SYSTEMS 3/4.6.5 COMBUSTIBLE GAS CONTROL HYDROGEN ANALYZERS LIMITING CONDITION FOR OPERATION 3.6.5.1 Two independent containment hydrogen analyzers shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

I -

ACTION:

f a.

With one hydrogen analyzer inoperable, restore the inoperable analyzer i

to OPERABLE status within 30 days or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

i b.

With both hydrogen analyzers inoperable, restore at least one inoperable analyzer to OPERABLE status within 72 'murs or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

?

i SURVEILLANCE REQUIREMENTS

{

4.6.5.1 Each hydrogen analyzer shall be demonstrated OPERABLE at least bi-

I weekly on a STAGGERED TEST BASIS by drawing a sample from the waste gas system through the hydrogen analyzer.

4.6.5.2 Each hydrogen analyzer shall be demonstrated OPERABLE at least once i

p per 92 days on a STAGGERED TEST BASIS by performing a CHANNEL CALIBRATION i

using sample gases in accordance with manufacturers' reconnendations.

CALVERT CLIFFS - UNIT 1 3/4 6-26 Amendment No. 58,7A,83,783, 109 m_

, 7 - - ___

s PLANT SYSTEMS AUXILIARY FEEDWATER SYSTEM LIMITING CONDITION FOR OPERATION 3.7.1.2 Two auxiliary feedwater trains consisting of one steam-driven and one motor-driven pump and associated flow paths capable of automatically initiating flow.shall be OPERABLE.

(An OPERABLE steam-driven train shall consist of one pump aligned for automatic flow initiation and one pump aligned in standby.)*

APPLICABILITY: MODES 1, 2 and 3.

ACTION:

A With any single pump inoperable, perform the following:

a.

1.

With No. 13 motor-driven pump inoperable:

3

)

(a) Align the standby steam-driven pump to automatic initiating status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , and (b) Restore No. 13 motor-driven pump to OPERABLE status within the next 7 days or be in HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

l 2.

With one steam-driven pump inoperable:

(a) Align the OPERABLE steam-driven pump to automatic initiating status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in HOT SHUTDOWN within the next l

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , and (b) Restoretheinoperablesteam-drivenpumptostandbystatus(or 4

automatic initiating status if the other steam-driven pump is to be placed in standby) within the next 7 days or be in HOT I

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

b.

With any two pumps inoperable:

1.

Verify that the remaining pump is aligned to automatic initiating status within one hour, and 2.

Verify within one hour that No. 23 motor-driven pump is OPERABLE and valve 2-CV-4550 has been exercised within the last 30 days, and 3.

Restore a'second punp to automatic initiating status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months l

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

A standby pump shall be available for operation but aligned so that automatic flow initiation is defeated upon AFAS actuation.

CALVERT CLIFFS - UNIT 1 3/4 7-5 Amendment No. 54.67,78.88,109

i PLANT SYSTEMS j

AUXILIARY FEEDWATER SYSTEM LIMITING CONDITION FOR OPERATION (Continued) 4 I

ACTION: '(Continued)

Whenever a subsystem (s) (a subsystem consisting of one pump, piping, valves c.

and controls in the direct flow path) required for operability is inoper-able for the performance of periodic testing (e.g. manual discharge valve closed for operator (s) pump Total Dynamic Head Test or Logic Testing) a dedicated will be stationed at the local station (s) with direct comuni-cation to the Control Room. Upon completion of any testing, the sub-system (s) required for operability will be returned to its proper status and verified in its proper status by an independent operator check.

d.

The requirements of Specification 3.0.4 are not applicable whenever one motor and one steam-driven pump (or two steam-driven pumps) are aligned for automatic flow initiation.

i' SURVEILLANCE REQUIREMENTS 1

i i

4.7.1.2 Each auxiliary feedwater flowpath shall be demonstrated OPERABLE:

j a.

At least once per 31 days by:

1 j

i 1.

Verifying that each steam-driven pump develops a Total Dynamic l

Head of >2800 ft. on recirculation flow (if verification must 1

be demonstrated during startup, surveillance testing shall be

[

performed upon achieving an RCS temperature > 300*F and prior toenteringMODE1).

, a,

]),

Verifying that the motor driven pump develops a Total Dynamic 2.

Head of >3100 ft. on recirculation flow.

4.

{

3.

Cycling each testable, remote-operated valve that.is not in its Operating position through at least one complete cycle.

4.

Verifying that each valve (manual, power operated or automatic) in the direct flow path is in its correct position.

b.

Before entering MODE 3 after a COLD SHUTDOWN of at least 14 days by I

completing a flow test that verifies the flow path from the condensate

storage tank to the steam generators.

At least once per 18 months by:

i c.

1 t

1.

Verifying that each automatic valve in the flow path actuates U

l to its correct position (verification of flow-modulating CALVERT CLIFFS - UNIT 1 3/4 7-Sa Amendment No. #7, 3 g

__,_,..____.,_____,.._,,_.,_,__._.__m.,_,,,,,,.____._.___...,

._..,_,_vLm_,-,_.-__,,.,_.--,,,,...,_.m._,__,,.,b

PLANT SYSTEMS AUXILIARY FEEDWATER SYSTEM

$URVEILLANCE REQUIREMENTS (Continued) characteristics not required) and each auxiliary feedwater pump automatically starts upon receipt of each AFAS test signal, and Verifying that the auxiliary feedwater system is capable of 2.

providing a minimum of 200 gpm nominal flow to each flow leg.

i 1

i

't i

CALVERT CLIFFS - UNIT 1 3/4 7-5b Amendment No.'57,SS. 109

,,---n

---e.----.n,n---,-y-.

. > +. - - -,.--,,,,,,, - -, - -. - -

.--.,,n,...

w-- -.,. --.,.

ELECTRICAL POWER SYSTEM SURVEILLANCE REQUIREMENTS (Continued) a.

At least once per 31 days on a STAGGERED TEST BASIS by:

1.

Verifying the fuel level in the day fuel tank.

2.

Verifying the fuel level in the fuel storage tank.

3.

Verifying the fuel transfer pump can be started and transfers fuel from the storage system to the day tank.

4.

Verifying the diesel starts from ambient condition and accelerates to at least 900 rpm in i 10 seconds.

5.

Verifying the generator is synchronized, loaded to 2.

1250 kw, and operates for 2. 60 minutes.

6.

Verifying the diesel generator is aligned to provide standby power to the associated emergency busses.

7.

Verifying that the automatic load sequence timer is OPERABLE with the interval between each load block within + 10% of its design interval.

b.

At least once per 92 days by verifying that a sample of diesel fuel from the fuel storage tank is within the' acceptable limits specified in Table 1 of ASTM D975-68 when checked for-viscosity,

~

water and sediment.

c.

At least once per 18 months by:

1.

Subjecting the diesel to an inspection in accordance with procedures prepared in conjunction with its manufacturer's recommendations for this class of standby service.

2.

Verifying the generator capability to reject a load of 1 500 hp without tripping.

l 3.

Simulating a loss of offsite power in conjunction with a safety injection actuation test signal,'and:

a) Verifying de-energization of the emergency busses and load shedding from the emergency busses.

CALVERT CLIFFS - UNIT 1 3/4 8-3 Amendment No.109 e

ELECTRICAL POWER SYSTEM _S l

SURVEILLANCE REQUIREMENTS (Continued) l b)

Verifying the diesel starts from ambient condition on the auto-start signal, energizes the emergency busses with pennanently connected loads, energizes the auto-connected emergency loads through the load i

sequencer and operates for > 5 minutes while its generator is loaded with the amergency loads.

c)

Verifying that all diesel generator trips, except i-engine overspeed, crankcase pressure high, lube oil pressure low, generator ground overcurrent, and f

. generator differential, are automatically bypassed on a Safety Injection Actuation Signal.

4.

Verifying the diesel generator operates for > 60 minutes i;

while leaded to > 2500 kw.

4 5.

Verifying that the auto-connected loads to each diesel

].

generator do not exceed the 2000, hour rating of 2700 kw.

!L P

i!')

I d

k f

l I

r i

I -

9 0

CALVERT CLIFFS-UNIT 1 3/4 8-4

s 3/4.3 INSTRUMENATION I.

~

EASES t

1 3/4.3.1 and 3/4.3.2 PROTECTIVE AND ENGINEERED SAFETY FEATURES (ESF)

INSTRUMENTATION The OPERABILITY of the

{

and bypasses ensure that 1) protective and ESF instrumentation systems the associated ESF action and/or reactor trip i

will be initiated when the parameter monitored by each channel or combi-l nation therof exceeds its setpoint, 2) the specified coincidence logic is i,

maintained 3) sufficient redundancy is maintained to permit a channel

~

to be out of service for testing or maintenance, and 4) sufficient system functional capability is available for protective and ESF purposes from diverse parameters.

i i

The OPERA 8ILITY of these systems is required to provide the overall reliability, redundance and diversity assumed available in the facility 1

design for the p*otection and mitigation of accident and transient con-ditions. The integrated operation of each of these systems is consistent I

with the assumptions used in the accident analyses.

I i

The surveillance requirements specified for these systems ensure that the overall system functional capability is maintained comparable l

to the original design standards. The periodic surveillance tests per-formed et the minimum frequencies are sufficient to demonstrate this l

capability.

1 The measurement of response time at the specified frequencies pro-l wides assurance that the protective and ESF action function associated with each channel is completed within the time limit assumed in the l

accident analyses. No credit was taken in the analyses for those channels j

with response times indicated as not applicable.

Response time may be demonstrated by any series of sequential, over-lapping or total channel test measurements provided that such tests i

demonstrate the total channel response time as defined. Sensor response time verification may be demonstrated by either 1) in place, onsite or offsite test measurements or 2) utilizing replacement sensors with certified response times.

f 3/4.3.3 MONITORING INSTRUMENTATION 1

3/4.3.3.1 RADIATION MONITORING INSTRUMENTATION The OPERA 8ILITY of the radiation monitoring channels ensures that

)

1) the radiation levels are continually measured in the areas served l

CALVERT CLIFFS - UNIT 1 8 3/4 3-1 L

INSTRUMENTATION BASES

~

l by the individual channels and 2) the alarm or automatic action is initiated when the radiation level trip set;>oint is exceeded.

j The Iodine and Particulate samplers were installed to meet the require-i ments of NUREG-0737 Item II.F.1. The samplers' operation was not assumed in

]

any accident analysis.

?

l 3/4.3.3.2 INCORE DETECTORS l

The OPERABILITY of the incore detectors with the specified minimum complement of equipment ensures that the measurements obtained from use I

I[

of this system accurately represent the spatial neutron flux distribution j,-

of the reactor core.

I' 3/4.3.3.3. SEISMIC INSTRUMENTATION The OPERASILITY of the seismic instrumentation ensures that sufficient capability is available to promptly determine the magnitude of a seismic l

event ar>d evaluate the response of those features important to safety.-

l This capability is required to pemit comparison of the measured response to that used in the design basis for the facility and is consistent with the

[i reconnendations of Regulatory Guide 1.12. " Instrumentation for Earthquakes "

April 1974.

g 3],4_.3.3.4 METEOROLOGICAL INSTRUMENTATION 6

1 The OPERA 8ILITY of the meteorological instrumentation ensures that s

sufficient meteorological data is available for estimating potential j

radiation doses to the public as a result of routine or accidental release j

of radioactive materials to the atmosphere. This capability is required j

to evaluate the need for initiating protective measures to protect the health and safety of the public and is consistent with the recommendations j

of Regulatory Guide 1.23 "0nsite Meteorological Programs," February 1972.

i 3/4.3.3.5 REMTE SHUTOOWN INSTRUENTATION l

l The OPERABILITY of the remote shutdown instrumentation ensures that l

sufficient capability is available to permit shutdown and maintenance of l

HOT STAN08Y of the facility from locations outside of the control room.

This c.spability is required in the event control room habitability is lost and is consistent with General Design Criteria 19 of 10 CFR 50.

t CALVEP.T CLIFFS - UNIT 1 B 3/4 3-2 Amendment No. 793, 109

.m.

- m.-..

,E-

]

e INSTRUMENTATION BASES

~

3/4.3.3.6 POST-ACCIDENT INSTRUMENTATION The OPERABILITY of the post-accident instrumentation ensures that sufficient information is available on selected plant parameters to monitor and assess these variables following an accident. This capability is consistent with the reconnendations of Regulatory Guide 1.97. "Instrumen-i tation for Light-Water-Cooled Nuclear Plants'to' Assess Plant Conditions During and Following a'n Accident," December 1975, and NUREG-0578, "TMI-2 l

Lessons Learned Task Force Status Report and Short-Term Reconnendations."

4

]

3/4.3.3.7 FIRE DETECTION INSTRUMENTATI_0N OPERABILITY of the fire detection instrumentation ensures that adequate warning capability is available for the prompt detection of fires. This capability is required in order to detect and locate fires j

i in their early stages. Prompt detection of fires will reduce the poten-tial for damage to safety related equipment and is an integral element in the overall facility fire protection program.

In the event that a portion of the fire detection instrumentation is inoperable, the establishment of frequent fire patrols in the affected 4

areas is required to provide detection capability until the inoperable j

instrumentation is restored to operability.

I i

l I

1 i

l 1

i i

CALVERT CLIFFS - UNIT 1 8 3/4 3-3 Amendment No. 28, 53, AW,109 i

r f

INSTRUMENTATION 4

BASES 3/4.3.3.9 RADIOACTIVE GASEOUS EFFLUENT MONITORING INSTRUMENTATTON The radioactive gaseous effluent instrumentation is provided to monitor and control, as applicable, the releases of radioactive materials in gaseous effluents during actual or potential releases of gaseous effluents. The alars/ trip setpoints for these instruments shall be calculated and adjusted I

in accordance with the methodology and parameters in the ODCM to ensure that the alarw/ trip will occur prior to exceeding the limits of Specifica-l tion 3.11.2.1.a based on average annual X/Q. The OPERABILITY and use of l

this instrumentation is consistent with the requirements of General Design Criteria 60, 63, and 64 of Appendix A to 10 CFR Part 50.

3/4.3.3.10 RADIOACTIVE LIQUID EFFLUENT MONITORING INSTRUMENTATION The radioactive liquid effluent instrumentation is provided to monitor and control, as applicable, the releases of radioactive materials in liquid 4

effluents during actual or potential releases of liquid effluents. The i

alarsvtrip setpoints for these instruments shall be calculated and adjusted in accordance with the methodology and parameters in the 00CM to ensure i

that the alars/ trip will occur prior to exceeding the limits of 10 CFR i

i Part 20. The OPERA 8ILITY and use of this instrumentation is consistent with the requirements of General Design Criteria 60, 63 and 64 of Appendix A to 10 CFR Part 50.

1 k

f i

l l

l CALVERT CLIFFS - UNIT 1 8.3/4 3-4 Amendment No.105

I i

314.6 CONTAINMENT SYSTEMS l

j BASES i

i 3/4.6.1 PRIMARY CONTAINMENT 3/4.6.1.1 CONTAINMENT INTEGRITY Primary CONTAINMENT INTEGRITY ensures that the release of radio-i i

active materials from the containmert atmosphere will be restricted to i

those leakage paths and associated leak rates assumed in the accident i

analyses. This restriction, in conjunction with the leakage rate limi-

]-

tation, will limit the site boundary radiation doses to within the limits of 10 CFR 100 during accident conditions.

~

]

3/4.6.1.2 CONTAINMENT LEAKAGE i

4 The limitations on containment leakage rates ensure that the total containment leakage volume will not exceed the value assumed in the j

accident analyses at the peak accident pressure P,r. As an added con-i servatism, the measured overall integrated leaka e ate is further 1

limited to < 0.75 L or < 0 t fob p(ossible degradation of the contain-I theperiodicteststoaccoun.75L as applicable during performance of l

ment leakage barriers between leakage tests.

1 i

The surveillance testing for measuring leakage rates are consistent j

with the requirements of Appendix "J" of 10 CFR 50.

]

3/4.6.1.3 CONTAINMENT AIR LOCKS i

The limitations on closure and leak rate for the containment air locks are required to meet the restrictions on CONTAINMENT INTEGRITY i

and containment leak rate. Surveillance testing of the air lock seals i

provides assurance that the overall air lock leakage will not become excessive due to seal damage during the intervals between air lock j

leakage tests.

i i

CALVERT CLIFFS - UNIT 1 8 3/4 6-1 l

1

)

-_,_x-_..

i i

j i

CONTAINMENT SYSTEMS BASES

~

i 3/4.6.1.4 INTERNAL PRESSURE The limitations on containment internal pressure ensure that 1) the containment structure is prevented from exceeding its design negative pressure differential with respect to the outside atmosphere of 3.0 psig j

and 2) the containment peak pressure does not exceed the design pressure i

of 50 psig during LOCA conditions.

i jj ~

The maximum peak pressure expected to be obtained from a LOCA event i;

is 47.6 psig. The limit of 1.8 psig for initial positive containment pressure will limit the total pressure to 49.4 psig which is less than

!,(

the design pressure and is consistent with the accident analyses.

) I' lf 3/4.6.1.5 AIR TEW ERATURE ttp The limitation on containment average air temperature ensures that the containment peak air temperature does not exceed the design temperature of j-276*F during LOCA conditions. The containment t y rature limit is h

consistent with the accident analyses.

4 f

n 3/4.6.1.6 CONTAll# U T STRUCTURAL INTEGRITY t

rl.

This limitation ensures that the structural integrity of the containment

(

will be maintained comparable to the original design standards for the life

]

of the facility. Structural integrity is required to ensure that the contain-k ment will withstand the maximum pressure of 47.6 psig in the event of a LOCA.

j The measurement of containment tendon lift off force, the visual and metal-lurgical examination of tendons, anchorages and liner and the Type A leakage tests are sufficient to demonstrate this capability.

The surveillance requirements for demonstrating the containment's structural integrity are consistent with the intent of the reconnendations of Regulatory Guide 1.35 " Inservice Surveillance of Ungrouted Tendons in Prestressed Concrete Containment Structures", January Ig76.

i The end anchorage concrete exterior surfaces are checked visually for i

indications of abnonnel material behavior during tendon surveillance.

Inspections of pre-selected concrete crack patterns are performed during the Type A containment leakage rate tests, consistent with the Structural j

Integrity Test.

i l

l l

CALVERT CLIFFS - UNIT 1 B 3/4 6-2 Amendment No.109

~~~---~~L=------

--. - - - - - = = = = = - -

=____.__m_

f W*hy%.

F UNITED STATES j

[

j NUCLEAR REGULATORY COMMISSION L

WASHINGTOad, D. C. 20555 4...

+0 4

i j

BALTIMORE GAS AND ELECTRIC COMPANY j

DOCKET NO. 50-318 i

l CALVERT CLIFFS NUCLEAR POWER PLANT UNIT NO. 2 1

i AMENOMENT TO FACILITY OPERATING LICENSE Amendment No. 92 License No. OPR-69 j,

1.

The Nuclear Regulatory Commission (the Commission) has found that:

i A.

The application for amendment by Baltimore Gas & Electric Company (thelicensee)datedApril 26, 1985 as supplemented by letter dated September 30, 1985, complies with the standards and requirements of 1

the Atomic Energy Act of 1954, as amended (the Act), and the Commission's rules and regulations set forth in 10 CFR Chapter I; 8.

The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the i

i Commission; C.

There is reasonable assurance (1) that the activities authorized by

,j this amendment can be conducted without endangering the health and safety of the public, and (11) that such activit.les will be r

I ll conducted in compliance with the Commission's regulations; D.

The issuance of this amendment will not be inimical to the connon Q-defense and security or to the health and safety of the public; and P

i E.

The issuance of this amendnent is in accordance with 10 CFR Part 51 of the Connission's regulations and all applicable requirements have i

heen satisfied.

1 l

4 i

2.

Accordingly, the license is amended by changes to the Technical Specifications as indicated in the attachment to this license amendment, and paragraph 2.C.2 of Facility Operating License No. DPR-69 is hereby amended to read as follows:

2.

Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 92, are hereby incorporated in the license. The licensee shall operate the facility in accordance with the Technical Specifications.

3.

This license amendment is effective as of the date of its issuance.

FOR THE NUCLEAR REGULATORY COMMISSION Asho C.* *T adani, Director PWR roject Directorate #8 Division of PWR Licensing-B

Attachment:

Changes to the Technical Specifications Date of Issuance: December 9,1985 k

5, a

t

9 ATTACHMENT TO LICENSE AMENDMENT NO. 92 FACILITY OPERATING LICENSE NO. DPR-69 DOCKET NO. 50-318 Replace the following pages of the Appendix "A" Technical Specifications with the enclosed pages. The revised pages are identified by amendment number and contain vertical lines indicating the areas of change. The corresponding overleaf pages are provided to maintain document completeness.

Remove Pages Insert Pages IV IV 3/4 3-26 3/4 3-26 3/4 3-28 3/4 3-28 3/3 3-45 3/4 3-45 3/4 3-46 3/4 3-46 4

g 3/4 3-47 3/4 3-47 4

3/4 6-8 3/4 6-8 l

3/4 6-9 3/4 6-9

!i 3/4 6-26 3/4 6-26 3/4 7-5a 3/4 7-Sa 3/4 8-3 3/4 8-3 8 3/4 3-2 8 3/4 3-2 B 3/4 3-3 B 3/4 3-3 g

8 3/4 6-2 8 3/4 6-2

'4 It i

l 1'; '

i e

INDEX LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REQUIREMENTS SECTION

~

PAGE 3/4.0 A P PL ICAB I L ITY...........................................

3/ 4 0-1 3/4.1 REACTIVITY C0!.' TROL SYSTEMS 3/4.1.1 B0 RATION CONTROL Shutdown Margin - T

> 200 F.......................

3/4 1-1 3yg 0

Shutdown Margin - T i 200 F.......................

3/4 1-3 av Baron Dilution.......g

................................. 3/4 1-4 Moderator Temperature Coefficient....................

3/4 1-5 Minimum Temperature for Criticality..................

3/4 1-7 2

3/4.1.2 BORATION SYSTEMS Flow Paths - Shutdown................................

3/4 1-8 Fl ow Pa ths - Op e ra ti n g.............................. 3/4 1 - 9 Charging Pump - Shutdown............................. 3/4 1 -10 Charging Pumps - Operating...........................

3/4 1-11 Boric Acid Pumps - Shutdown.......................... 3/4 1 -12 Bori c Acid Pumps - Operating......................... 3/4 1 -13 Borated Wa ter Sources - Shutdown..................... 3/4 1 -14 Borated Wa ter Sources - Operating....................

3/4 1 -16 3/4.1.3 MGVABLE CONTROL ASSEM3 LIES Full Length CEA Posi tion.. :.......................... 3/4 1 -17 Position Indicato r Channel s.......................... 3/4 1-21 C EA Drop T i me........................................

3/ 4 1 - 2 3 Shutdown CEA Insertion Limits........................ 3/4 1-24 Regulating CEA Insertion Limits......................

3/4 1-25 CALVERT CLIFFS - UNIT 2 III Amendment No. JE,B1 e

k 1

=

INDEX 1

LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REQU l

t SECTION PAGE 3/4.2 POWER DISTRIBUTION LIMITS 3/4.2.1 L INEAR HEAT RATE...................................

3/4.2.2 TOTAL PLANAR RADIAL PEAKING FACT 3R....................

3/4 2-6 3/4.2.3 TOTAL INTEGRATED RADIAL PEAKING FACTOR................

3/4 2-9

}i 3/4.2.4 AZIMUTHAL POWER TILT............................

4 e 1

i 3/4.2.5 DNS PARAMETERS............................~...~.........

3/4 2-13 i

i 1

3/4.3 INSTRUMENTATION 3/4.3.1 REACTOR PROTECTIVE INSTRUMENTATION....................

3/4 3-1

b'.

3/4.3.2 ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION..................................... 3/4 3-10 i!

jj 3/4.3.3 MONITORING INSTRUMENTATION i

1 p

Radiation Moni toring Instrumen ta tion.................. 3/4 3-25 4

Incore De t ecto rs....................................

b Seismi c Instrumentation........................

s b

3/4 3-31 Heteorological Instrumentation........................

3/4 3-34 Y

Remote Shutdown Instrumentation...................

Post Accident Instrumentation.....................

1 p[

Fi re Detection Instrumentation....................

i

{

Radioactive Gaseous Effluent Monitoring Instrumenta tion..................................

Radioactive Liquid Effluent Monitoring l

Instrumentation.....................................

3/4 3-53 3/4.4 REACTOR COOLANT SYSTEM i

3/4.4.1 COOLANT LOOPS AND COOLANT CIRCULATION.....

i Startup and Power.................................... 3/4 4-1 g

........... 3/4 4-1

{

Hot Standby.........'..................

5hutdown..............................

............... 3/4 4-2 l

............... 3/4 4-2a 3/4.4.2 SAFETY VALVES.........................................

3/4 4-3 3/4.4.3 REL IEF VALVES...............................

CALVERT CLIFFS - UNIT 2 IV Amendment Nc.JJ 7% 75 U.' AS.' 92 t

e.

~

II;STRUMENTATION 3/4.3.3 MONITORING INSTRUMENTATION RA0!ATION MONITORING INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.3.1 The radiation monitoring instrumentation channels shown in Table 3.3-6 shall be OPERABLE with their alarm / trip setpoints within the specified limits.

APPLICABILITY: As shown in Table 3.3-6.

ACTION:

With a radiation monitoring channel alarm / trip setpoint a.

exceeding the value shown in Table 3.3-6, adjust the set-point to within the limit within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months or declare the channel inoperable.

b.

With one or more radiation monitoring channels inoperable, take the ACTION shown in Table 3.3-6.

The provisions of Specifications 3.0.3 and 3.0.4 are not c.

applicable.

I SURVEILLANCE REOUIREMENTS i

\\

t 4.3.3.1 Each radiation monitoring instrumentation channel shall be demonstrated OPERABLE by the perfomance of the CHANNEL CHECK, CHANNEL i

CALIBRATION and CHANNEL FUNCTIONAL TEST operations during the modes nd at the frequencies shown in Table 4.3-3.

a G

CALVERT CLIFFS - UNIT 2 3/4 3-25

/4 0

._..e.

..m....em..-

semasa.

-u

_ TABLE 3.3-6 RADIATION N0flITORING INSTRUMENTATION MINIMUM i

n CHANNELS APPLICABLE ALARM / TRIP MEASUREMElli i'

C INSTRUMENT OPERABLE MODES

_SETP0lfir RAflGE ACTI0ff 4

e'

1. AREA MONITORS e

g g

-a.

Containment 1.

Purge & Exhhust m

Isolation 3

6 4

4 1 220 mr/hr 10

- 10 mr/hr 16 b.

Containment Area High Range 2

1. 2, 3 & 4 1 10 R/hr 1 - 10 R/hr 30 8

2.

PROCESS H0!!! TORS u

A

a. -Containment 1.

Gaseous Activity a) RCS Leakage Detection 1

1. 2. 3 & 4 Not Applicabic 10 - 10 cpm 14 I

6

11. Particulate Activity a) RCS Leakage k

Detection 1

1. 2. 3 & 4 Not Appl { cable 10 - 10 cpm 14 1

6 b.

Effluent Monitors S

1.

Main Vent Wide g

Range a

Noble Gas 1

1. 2. 3 & 4

-7 5

10 to 10 pCi/cc 30 g

b Iodine Sampler 1

1. 2, 3 & 4 Not Applicable flot Applicat le 8 30 c

Particulate t

,5 Sampler 1

1. 2, 3 & 4 Not App 1tcable flot Appitcable 30 f

E

Alam setpoint to bd speelffed in a controlled document (e.g., setpoint control manual).

y

_ TABLE 3.3-6 (Continued)

TABLE NOTATION ACTION 14 - With the number of channels OPERABLE less than requi by the Minimum Channels OPERABLE requirement, comply with the ACTION requirements of Specification 3.4.6.1.

i ACTION 16 - With the number of channels OPERABLE less than requir j

by the Minimum Channels OPERABLE requirement, comply with the ACTION requirements of Specification 3.9.9.

ACTION 30 - With the number of channels OPERABLE less than requ by the Minimum Channels OPERABLE. requirement, initiate f.

the preplanned alternate method of monitoring the I

appropirate parameter (s), within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , and:

1) eitherrestoretheinoperabkechannel(s)toOPERABLE i

status within 7 days of the event, or 2) prepare and sumbit a Special Report to the Comission pursuant to Specification 6.9.2 within 30 days following the event outlining the action taken, the cause of the inopera,bility and the plans and schedule for restoring the system to OPERABLE status, j

t k

CALVERT CLIFFS - UNIT 2 3/4 3-27 Amendment No. 81

m u

JABLE 4.3-3 h

El RADIATION MONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTS

--s p

CilANNEL MODES Ill WilICil CHANNEL CilANilEL FUNCTIONAL SURVEILLANCE INSTRt! MENT i

3

_ CHECK CALIBRATION TEST j

1.

AREA MONITORS REQUIRED c=

i E

a.

Containment a

y 1.

Purge & Exhaust Isolation S

R H

6 b.

Containment Area High Range S

R H

1, 2, 3 & 4 f

y 2.

PROCESS HONITORS

{

a.

Contafnment l

1.

Gaseous Activity 4

a) RCS Leakage Detection S

R H

1, 2, 3 & 4

11. Particulate Activity y

a) RCS Leakage 3

Detection S

R H

1, 2, 3 & 4 3

b. -Effluent Monitors

=

1.

Main Vent Wide Range a) Noble Gas S

R H

1, 2, a & 4'

.O b)

Iodine Sampler M*

Not Applicable Not Appitcable 1, 2, 3 & 4 c) Particulate Sampler M*

Not Applicable Not Applicable 1,'2, 3 5 4

The Ci!4NNEL,CilECK shall be accomplished by comparing samples independently drawn l

TABLE 3.3-11 FIRE DETECTION INSTRUMENTS.

UNIT 2 MINIMUM INSTRURENTS OPERABLE

AUX BLDG INSTRUMENT LOCATION HEAT FLAME SMOKE 101/120 ECCS Pump Room L

102/121 ECCS Pump Room 7

105 Charging Pump Room 7

106 Misc Waste Monitor Tank 3

107/109 Coolant Waste Monitor Tank 1

108 4

PumpRoom-Elev(-)10'-0" 201 Component Cooling Pump Rm 1

203 East Piping Area 9

204 Rad Exhaust Vent. Equip Rm 10 j

205 Service Water Pump Rm 4

t 206/310 East Piping Pen Rm 3

6 211/321 West Piping Pen Rm 3

5 1

213 Degasifier Pump Rm 2

3 214 Volume Control Tank Rm 1

1 215 Boric Acid Tank & Pump Rm 1

216A 302/2C Reactor Ccolant Make-up Pumps 2

U2 Cable Spreading Rm & Cable Chase ** 2 2

305/307/303 o

U2 Battery Rm & Corridor 10 309 Main Steam Piping Area 3

f 311 Switchgear Rm Elev 27'-0" 6

312 Purge Air Supply Rm 6

322 Letdown He=tt Exchanger Rm 2

Eley. 27'-0" Switchgear Vent Duct 1

2A Cable Chase 2A 1

28 Cable Chase 28 1

407 Switchgear Rm, Elev 45'-0"**

1 408 East Piping Area 8

409 East Electrical Pen Rm 7

414 West Electrical Pen Rm 3

416 440 DieselGeneratorNo.(21)**

3 2

Refueling Water Tank Pump Rm Elev 45'-0" Switchgear Vent Duct 1

2

.526 527 Main Plant Exhaust Equip Rm Containment Access 8

532 Electrical Equip Rm 3

Eley. 69'-0" Cable Spreading Room Vent Duct 3

Elev. 83'-0" Cable Tunnel 1

605 Auxiliary Feedwater Pump Rm 4

2 s

CALVERT CLIFFS - UNIT 2 3/4 3-45 Amendment No U,4,77, 92 4

.n-.

~.

t

=

L I

TABLE 3.3-11 (Continued)

FIRE DETECTION INSTRUMENTS

~

UNIT 2 2

I' ROOM / AREA MINIMUM INSTRUMENTS OPERABLE *

.i

_ AUX BLDG INSTRUMENT LOCATION HEAT

_C_ontainment B1 dos.

FLAME SM0KE

,L UNIT 2 RCP Bay East

II UNIT 2 RCP Bay West

16 UNIT 2 East Electric Pen Area

16.+.

i UNIT 2 West Electric Pen Area *

+

Intake Structure Elev 3'-0" Unit 2 Side t

24 i

i 4

i:

h i

i 4

l

,i ii i

I

Detection instruments located within the containment are not required to be i

- Detectors which automatically actuate fire suppression sy

+ Monitored by four protecto wires.

CALVERT CLIFFS - UNIT 2 3/4 3-46 Amendment No. 77. 92 i

. _. ~ _ _ _ _ _ _ - _.

i t

+

i.

g i

t t

i r

4 i

i i

1 THIS PAGE, INTENTIONALLY LEFT BLANK 3

L 1

e

~

4 i

j 2

1 1

1 I

1 i

J i

i i

1 f

4 i

1i 1

i i

!i.I a

1 1

I 1

i ii j

CALVERT CLIFFS - UNIT 2 3/4 3 47 Amendment No. 81, 92 1

i f

i

= _ _... _ _,

l' CONTAINMENT SYSTEMS AIR TEMPERATURE LIMITING CONDITION FOR OPERATION 3.6.1.5 120*F.

Primary containment average air temperature shall not exceed APPLICABILITY: MODES 1. 2. 3 and 4.

ACTION:

With the containment average air temperature > 120*F. reduce the averag air temperature to within the limit within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months , or be in at least HOT 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 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

1 6

4 w

SURVEILLANCE REQUIREMENTS 4.6.1.5 The primary containment average air temperature shall be the arithmetical average of the temperatures at the following locations and shall be detennined at least once per 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months s:

t Location

?

a.

Containment Dome b.

Containment Reactor Cavity i

I i

<,CALVERT CLIFFS - UNIT 2 3/4 6-7

.I r

_ = _

p i

CONTAINMENT SYSTEMS i

CONTAINMENT STRUCTURAL INTEGRITY l

~

LIMITING CONDITION FOR OPERATION i

3.6.1.5 The structural integrity of the containment shall be maintained at a level. consistent with the acceptance criteria in Specification 4.6.1.6.

APPLICABILITY: MODES 1, 2, 3 and 4.

ACTION:

With the structural integrity of the containment not conforming to the above requirements, restore the structural integrity.to within the limits within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COL SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

I SURVEILLANCE REQUIREMENTS 4.6.1.6.1 Containment Tendons.

shall be demonstrated at the end of one, three and five years followi i

initial containment structural integrity test and at five year intervals i

thereafter.

The tendons' structural integrity shall be demonstrated by a visual examination (to the extent practical and without dismantling load bearing components of the anchorage) of a re 21 tendons (6 dome, 5 vertical, and 10 hoop)presentative sample of at least and verifying no abnormal degradation.

Unless there is evidence of abnormal degradation of the containment structure during the first three tests of the tendons, the number of-tendons examined during subsequent tests may be reduced to a.representa-tive sample of at least 9 tendons (3 dome, 3 vertical and 3 hoop).

4.6.1.6.2 End Anchorages and Adiacent Concrete Surfaces. The structural integrity of the end anchorages and adjacent concrete surfaces shall be demonstrated by determining through inspection of a representative sample of tendons (reference Specification 4.6.1.6.1) that no apparent changes have occurred in the visual appearance of the end anchorages or their 1

adjacent concrete exterior surfaces.

4' Also, inspections of the-pre-selected concrete crack patterns adjacent to end anchorages shall be performed durin the Type A containment leakage rate tests (reference S while the containment is at its maximum test pressure.pecification 4.6.1.2 4

3 CALVERT CLIFFS - UNIT 2 V.

' 3/4i6-8

' Amendment No. 92 4

g 4

4 1

_..-._..___.-.._._,-,,.,,,,i,__-..--,,_-..,m_.__.#_._.,

..... -...~.a.a

CONTAINMENT SYSTEMS SURVEILLANCE REQUIREMFNTS (Continued) 4.6.1.6.3 Contain' ment Surfaces. The exposid accessible interior and exterior surfaces of tne containment, including the liner plate shall be visually inspected during the shutdown for each Type A containment leakage rate test (reference Specification 4.6.1.2).

to the Type A containment leakage rate test to uncover any evidence ofT structural deterioration which may affect either the containment structural integrity or leak tightness.

4.6.1.6.4 Reports.

Any abnormal degradation of the containment structure detected during the above required tests and inspections shall be reported This report shall include a description of the tendon conditio P

condition of the concrete (especially at tendon anchorages), the inspec-I tion procedure, the tolerances on cracking, and the corrective actions taken.

l L.

CALVERT CLIFFS - UNIT 2 3/4 6-9 Amendment No. 75, 92

~

s v

M-V l

t b

' CONTAINMENT SYSTEMS CONTAINMENT PURGE SYSTEM

~

LIMITING CONDITION FOR OPERATION 3.5.1.7 The containment purge supply and exhaust isolation valves shall be closed by isolating air to the air operator and maintaining the solenoid air supply valve deenergized.

?

APPLICABILITY:

MODES 1, 2, 3 and 4 ACTION:

a.

With one containment purge supply and/or one exhaust isolation valve open close the opea valve (s) within one hour or be in at least 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 hou b.

With one containment purge supply and/or one 4 l

be in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

F

. SURVEILLANCE REOUIREMENTS 4.6.l.7 be detennined closed at least once per 31 days, by verify olenoid valve is removed.

s CkLVERTCLIFFS-UNIT 2

~

3/4 6-9a Amendment No. idf,7 6

\\

=

.{

TABLE 3.6-1 (Continued)"

_CONTAIHilENT ISOLATION VALVES E!

PENETRATION ISOLATION ISOLATION VALVE NO.

CilAtlNEL

_ IDENTIFICATION NO.

ISOLATION'

.P FUNCTIOff 61 NA -

TIl1E (SEC0HDS)

SFP-184 NA SFP-182 Refuelfng Pool Dut1et flA NA SFP-180 NA c

NA SFP-186 z

ilA Z

NA 62 SIAS A PH-6579-MOV Contatnment Heating Outlet

-.13 64 NA PH-387 Containment Heating'Intet

.HA (1)

Manual or remote manual valve which is closed during plant operation w3 p

(2)

May be opened below 300*F to establish shutdown cooling flow.

'(3). Containment purge and containment vant isobtion valves whil b t

TS 3/4 6.1.7 and TS 3/4 6.1.8, respectively.

e shut in MODES 1, 2, 3 and 4 per

May be open on an intermittent basis under administrative control.

[

- Containment purge isolation valves isolation times will only apply in MODE 6 w t

required to be OPERABLE and they are open.

I during which time these valves must remain closed. vent isolation valves re I

[

.., respectively, U

3 2

I I

4 a

i a

_ CONTAINMENT SYSTEMS 3/4.6.5 COM3USTIBLE GAS CONTROL HYDRGGEN ANALYZERS LIMITING CONDITION FOR OPERATION 3.6.5.1 Two independent containment hydrogen analyzers shall be OPERA APPLICABILITY: MODES 1 and 2.

ACTION:

With one hydrogen analyzer inoperable, restore the inoperable a a.

to OPERABLE status within 30 days or be in at least HOT STANDBY l

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

t b.

With both hydrogen analyzers inoperable, restore at least one inop analyzer 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 within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

SURVEILLANCE REQUIREMENTS 4.6.5.1 Each hydrogen analyzer shall be demonstrated OPERABLE at lea biweekly on a STAGGERED TEST BASIS by drawing a sample fro System through the hydrogen analyzer indicator.

1

[

4.6.5.2 Each hydrogen analyzer shall be demonstrated OPERABLE at least TION using sample gases in accordance with man

[

l I

CALVERT CLIFFS - UNIT.2 3/4 6-26 Amendaent No. A2.55.66. 92

,, ~

m w -

4 PLANT SYSTEMS AUXILIARY FEEDWATER SYSTEM i

LIMITING CONDITION FOR OPERATION

~

3.7.1.2 Two auxiliary feedwater trains consisting of one steam driven and one motor driven pump and associated flow paths capable of automatically initiating flow shall be OPERABLE.

(An OPERABLE steam driven train shall consist of one I

pump aligned for automatic flow initiation and one pump aligned in standby.)*

j APPLICABILITY: MODES 1. 2 and 3.

ACTION:

4 With any single pump inoperable, perform the.following:

I a.

l.

With No. 23 motor-driven pump inoperable:

(a) Align the s'tandby steam-driven pump to automatic initiating status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , and (b) Restore No. 23 motor-driven pump to OPERABLE status within the next 7 days or be in HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

2.

With one. steam-driven pump inoperable:

I (a) Align the OPERABLE steam driven pump to automatic initiating I status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , and (b) Restore the inoperable steam driven pump to standby status I

(or automatic initiating status if the other steam driven pump is to be placed in standby) within the next 7 days or l

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

l b.

With any two pumps inoperable:

1.

Verify that the remaining pump is aligned to automatic initi-ating status within one hour, and 2.

Verify within one hour that No.13 motor driven pump is OPERASLE and valve 1-CV-4550 has been exercised within the last 30 days, and 3.

Restore a second pump to automatic initiating status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

A standby pump shall be available for operation but aligned so that automatic flow initiation is defeated upon AFAS actuation.

l CALVERT CLIFFS - UNIT 2 3/4 7-5 Amendment No. 37, #, #1, #2, 78 t

i PLANT SYSTEMS AUXILIARY FEEDWATER SYSTEM i

LIMITING CONDITION FOR OPERATION (Continued)

Whenever a subsystem (s) (a subsystem consisting of one-pump, piping, c.

valves and controls in the direct flow path) required for operability is inoperable for the performance of periodic testing (e.g. manual discharga valve closed for pump Total Dynamic Head Test or Logic Testing) a dedicated operator (s) will be stationed at the local station (s) with direct comunication to the Control Room. Upon completion of any testing, the subsystem (s) required for operability will be returned to its proper status and verified in its proper status by an independent operator check.

d.

The requirements of Specification 3.0.4 are not applicable whenever one motor and one steam-driven pump (or two steam-driven pumps) are aligned for automatic flow initiation.

SURVEILLANCE REOUIREMENTS 4.7.1.2 Each auxiliary feedwater flowpath shall be demonstrated OPERABLE:

At least once per 31 days by:

a.

1.

Verifying that each steam driven pump develops a Total Dynamic Head of > 2800 ft. on recirculation flow..(Ifverification must be demonstrated during startup, surveillance testing shall be perfonned upon achieving an RCS temperature 1300"F and prior to entering MODE 1).

2.

Verifying that the motor driven pump develops a Total Dynamic Head of 1 3100 ft. on recirculation flow.

3.

Cycling each testable, remote operated valve that is not in its operating position through at least one complete cycle.

4.

Verifying that each valve (manual, power operated or automatic) in the direct flow path is in its correct position.

b.

Before entering MODE 3 after a COLD SHUTDOWN of at least 14 days by completing a flow test that verifies the flow path from the conden-sate storage tank to the steam generators.

At least once per 18 months by:

c.

Verifying.that each automatic valve in the flow path actuates to a.

its correct position (verification of flow-modulating character-istics not required) and each auxiliary feedwater pump auto-matica11y starts upon receipt of each AFAS test signal, and 2.

Verifying that the auxiliary feedwater system is capable of providing a minimum of 200 gpm nominal flow to each flow leg.

CALVERT CLIFFS, UNIT 2 3/4 7-Sa Amendment No. M.52.78. 92

.. -... _. l.2.. :.:L

' " ~ ~ ~ ~ ~ * ' '

~~

m.

i

_ ELECTRICAL POWER SYSTEM SURVEILLANCE RE0VIREMENTS (Continued)

At least once per 31 days on a STAGGERED TEST BASIS by:

a.

1.

Verifying the fuel level in the day fuel tank.

l 2.

Verifying the fuel level in the fuel storage tank.

3.

Verifying the fuel transfer pump can be started and transfers fuel from the storage system to the day tank.

h I. ~

4.

Verifying the diesel starts from dbient condition and accelerates to at least 900 rpm in 5,10 seconds.

5.

Verifying the generator is synchronized, loaded to 1

~

1250 kw, and operates for 160 minutes.

6.

Verifying the diesel generator is aligned to provide standby power to the associated emergency busses.

7.

Verifying that the automatic load sequence timer is L

OPERABLE with the interval between each load block with

+ 10% of its design interval.

b.

At least once per 92 days by verifying that a sample of diesel fuel from the fuel storage tank is within the acceptable limits water and sediment.specified in Table 1 of ASTM D975-68 when che 5

At least once per 18 months by:

c.

I 1.

Subjecting the diesel to an inspection in accordance with procedures prepared in conjunction with its manufacturer's recomendations for this class of standby service.

{

2.

Verifying the generator capability to reject a load of

}

500 hp without tripping.

1.

I 3.

Simulating a loss of offsite power in conjunction with a safety injection actuation test signal, and:

1.

Verifying de-energization of the emergency busses and load shedding from the emergency busses.

CALVERT CLIFFS - UNIT 2 3/4 8-3 Amendment No. 92

+g+

~

i

' ELECTRICAL POWER SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) b)

Verifying the diesel starts from ambient condition on the auto-start signal, energizes the emergency busses with permanently connected loads, energizes the auto-connected emergency loads through the load sequencer and operates for > 5 minutes while its generator is loaded with the emergency loads.

c)

Verifying that all diesel generator trips, except engine overspeed crankcase pressure high, lube oil I

(~

pressure low, gen,erator ground overcurrent, and generator differential, are automatically bypassed on a Safety Injection Actuation Signal.

4.

Verifying the diesel generator operates for > 60 minutes t

while loaded to > 2500 kw.

~

[

~

i 5.

i Verifying that the auto-connected loads to each diesel i

generator do not exceed the 2000 hour0.0231 days 0.556 hours 0.00331 weeks 7.61e-4 months rating of 2700 kw.

I i

!f 6

8 CALVERT CLIFFS-UNIT 2 3/4 8-4

~

ep

ee W

~l1

}

t i

g3/4.3 INSTRUMENATION t

i BASES

~

L t

3/4.3.1 and 3/4.3.2 PROTECTIVE AND ENGINEERED SAFETY FEATURES (ES INSTRUMENTATION The OPERABILITY of the protective and ESF instrumentation systems and bypasses ensure that 1) the associated ESF action and/or reactor trip will be initiated when the parameter monitored by each channel or combi-nation therof exceeds its setpoint, 2) the specified coincidence logic is maintained, 3) sufficient redundancy is maintained to permit a channel to be out of service for testing or maintenance, and 4) sufficient system functional capability is available for protective and ESF purposes from diverse parameters.

)

t s

The OPERABILITY of these systems is required to provide the overall reliability, redundance and diversity assumed available in the facility e

design for.the protection and mitigation of accident and transient con-ditions.

The integrated operation of each of these systems is consistent with the assumptions used in the accident analyses.

The surveillance requirements specified for these systems ensure that the overall system functional capability is maintained comparable to the original design standards. The periodic surveillance tests per-formed at the minimum frequencies are sufficient to demonstrate this capability.

~

The measurement of-response time at the specified frequencies pro-vides assurance that the protective and ESF action function associated with each channel is completed within the time limit assumed in the accident analyses. No credit was taken in the analyses for those channels with response times indicated as not applicable.

Response time rey be demonstrated by any series of sequential, over-lapping or total channel test measurements provided that such tests demonstrate the total channel response time as defined.

Sensor response time verification may be demonstrated by either 1) in place, onsite or offsite test measurements or 2) utilizing replacement sensors with certified response times.

k 3/4.3.3 MONITORING INSTRUMENTATION 1

3/4.3.3.1 RADIATION MONITORING INSTRUMENTATION The OPERABILITY of the radiation monitoring channels ensures that

1) the radiation levels are continually measured in the areas served CALVERT CLIFFS - UNIT 2 -

B 3/4 3-1 m

.I_NSTRUMENTATION l

BASES 1

by the individual channels and 2) the alarm or autcmatic action Is initiated when the radiation level trip setpoint is exceeded.

ments of NUREG-0737 Item II.F.1.The iodine and particulate samplers we any accident analysis.

The samplers' operation was not assumed in i

3,/4.3.3.2 INCORE DETECTORS

}

The OPERABILITY of the incore detectors with the specified minimum complement of equipment ensures that the measurements obtained from use i

of this system accurately represent the spatial neutron flux distribution of the reactor core.

!l

)

3/4.3.3.3 SEISMIC INSTRUMENTATION

'i capability is available to promptly determine the magnit

[

,5 event and evaluate the response of those features important to safety.

capability is required to permit comparison of the measured response to that This

}

used in the design basis for the facility and is censistent with the it recosmendations of Regulatory Guide 1.12. " Instrumentation for Earthquakes "

April 1974.

f

,3/4.3.3.4:. METEOROLOGICAL INSTRUMENTATION The OPERABILITY of the meteorologica1' instrumentation ensures that tion doses to the public as a result of routine or accide ay radioactive materials to the atmosphere.

This capability is required to

' evaluate the need for initiating protective measures to protect the health and safety of the public and is consistent with the reconnendations of of Nuclear Power Plants," September 1980. ~ Regulatory Guid i

3/4.3.3.5 REMOTE SHUTDOWN INSTRUMENTATION The OPERABILITY of the remote shutdown instru:nentation e sufficient capability is available to permit shutdown and maintenance of HOT STANDBY of the facility from locations outside of the control room T

nd is consistent with General Design Criteria 19 of 10 C a

1 4

CALVERT CLIFFS - UNIT 2 B 3/4 3-2 Amendment No.85, 92 i.

l

~

l - --

\\

INSTRUMENTATION

-BASES 3/4.3.3.6 POST-ACCIDENT INSTRUMENTATION sufficient information is available on selected plant p monitor and assess these variables following an accident.

is consistent with the recommendations of Regulatory Guide 197This capabi mentation 'for Light-Water-Cooled Nuclear Plants to Assess Plant Conditio "Instru-During and Following an Accident," December 1975, and NUREG-0578 Lessons Learned Task Force Status Report and Short-Term Recommen t.

3/4.3.3.7 FIRE DETECTION INSTRUMENTATION t

OPERALILITY of the fire detection instrumentation ensures I

adequate warning capability is available for~the prompt detection of fires.

in their early stages.This capability is required in order to detect and loca

{

tial for damage to safety related equipment and is an integ l

in the overall facility fire protection program.

is inoperable, the estaolishment of frequent fire patro areas is required to provide detection capability until the inoperable e affected instrumentation is restored to coerability.

9 i

CALVERT CLIFFS - UNIT 2 -

B 3/4 3-3 Amendment No. JJ, 36,24,92

' " " ' ' ^ * '

ew' en

.,p, 4

,y

7 INSTRUMENTATION f

BASES i*

3/4.3.3.9 RADIOACTIVE GASEOUS EFFLUENT MONITORING INSTRUM control, as applicable, the releases of radioactive ma t

effluents during actual or potential releases of gaseous effluents.

alam/ trip setpoints for these instruments shall be calculated and adjusted The in accordance with the methodology and parameters in the ODCH to ensu tion 3.11.2.1.a based on average annual X/Q. The O I

l Criteria 60, 63, and 64 of Appendix A to 10 CFR Part 50.t 3/4.3.3.10 RADI0 ACTIVE LIQUID EFFLUENT MONITORING INSTRUM The radioactive liquid effluent instrumentation is provided to monitor and

(.

control, as applicable, the releases of radioactive materials in liquid effluents during actual or potential releases of liquid effluents.

g alarm / trip setpoints for these instruments shall be calculated and adj t

The in accordance with the methodology and parameters in the ODCM to en i

.that the alam/ trip will occur prior to exceeding the limits of 10 CFR l

P~ art 20.

The OPERABILITY and use of this instrumentation is con with the requirements of General Design Criteria 60, 63 and 64 of App

?

to 10 CFR Part 50.

e I

t lt e

f

. CALVERT CLIFFS - UNIT 2 B 3/4 3-4 Amendment No. 86

.. = -

.g,--..e--

3/4.6 CONTAINMENT SYSTEM 3 BASES e

3/4.6.1 PRIMARY CONTAINMENT 3/4.6.1.1 CONTAINMENT INTEGRITY Primary CONTAINMENT INTEGRITY ensures that the release of radio-active materials from the containment atmosphere will be restricted to those leakage paths and associated leak rates assumed in the accident analyses.

This restriction, in conjunction with the leakage rate limi-tation, will limit the site boundary radiation doses to within the limits of 10 CFR 100 during accident conditions.

3/4.6.1.2 CONTAINMENT LEAXAGE The limitations on containment leakage rates ensure that the total containment leakage volume will not exceed the value assumed in the accident analyses at the peak accident pressure, P,r.

As an added con-servatism, the measured overall integrated leakage ate is further limited to < 0.75 L or 0

theperiodictestsloac'c<oun.75Ltfofp(asapplicable)duringperformanceof ossible degradation of the contain-ment leakage barriers between leakage tests.

4 The surveillance testing for measuring leakage rates are consistent with the requirements of Appendix "J" of 10 CFR 50.

4 1

3/4.6.1.3 CONTAINMENT AIR LOCKS

!i n

The limitations on closure and leak rate for the containment air i.

locks are required to meet the restrictions on CONTAINMENT INTEGRITY and containment leak rate.

Surveillance testing of the air lock seals provides assurance that the overall air lock leakage will not become excessive due to seal damage during the intervals between air lock leakage tests.

CALVERT CLIFFS - UNIT 2 B 3/4 6-1 l

1

*W*f

L CONTAINMENT SYSTEMS t

BASES

~

3/4.6.1.4 INTERNAL PRESSURE The limitations on containme0t internal pressure ensure that 1) the containment structure is prevented from exceeding its design negative differential with respect to the outside atmosphere of 3.0 psig and 2) pressure the containment peak pressure does not exceed the design pressure of 50 psig during LOCA conditions.

The maximum peak pressure expected to be obtained from a LOCA event is 47.6 psig.

The limit of 1.8 psig for initial positive containment 1

pressure will limit the total pressure to 49.4 psig which is less than the design pressure and is consistent with the accident analyses.

3/4.6.1.5 AIR TEMPERATURE The limitation on containment average air temperature ensures that the containment peak air temperature does not exceed the design temperature of 276*F during LOCA conditions. The containment temperature limit is consis-l tent with the accident analyses.

3/4.6.1.6 CONTAINMENT STRUCTURAL INTEGRITY This limitation ensures that the structural integrity of the contain-ment will be maintained comparable to the original design standards for the life of the facility. Structural integrity is required to ensure that the containment will withstand the maximum pressure of 47.6 psig in the event of a LOCA.

1 The measurement of containment tendon lift off force, the visual and metallurgical examination of tendons, anchorages and liner and the Type A 1eakage tests are sufficient to demonstrate this capability.

l l

i i

The surveillance requirements for demonstating the containment's t

l structural integrity are consistent with the intent of the reconnendations I

l of Regulatory Guide 1.35 " Inservice Surveillance of Ungrouted Tendons.in Prestressed Concrete Containment StructuresJ January 1976.

i ndications of abnormal material behavior during tendon sur i

i i

I ype A containment leakage rate tests, consistent with the Str T

Integrity Test.

l l

' CALVERT CLIFFS - UNIT 2 8 3/4 6-2 Amendment No. 62 c

$I

[._.

m.

2:.--.

=

D

_

ML20138Q139

Contents

Text

Attachment:

= = =

Attachment:

Navigation menu

ML20138Q139

Text

Attachment:

= = =

Attachment:

Navigation menu

Search