Text

Tech Spec Pages for Amendment 282 Regarding Limiting Safety System Settings and Instrumentation
	ML032691406
Person / Time
Site:	Millstone
Issue date:	09/25/2003
From:	; NRC/NRR/DLPM/LPD1
To:	;
References
	TAC MB5008
	Download: ML032691406 (34)
	v • d • e

INSTRUMENTATION 3/4.3.2 ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.2.1 The engineered safety feature actuation system instrumentation channels and bypasses shown in Table 3.3-3 shall be OPERABLE with their trip setpoints set consistent with the values shown in the Trip Setpoint column of Table 3.3-4.

APPLICABILITY: As shown in Table 3.3-3.

ACTION:

a. With an engineered safety feature actuation system instru-mentation channel trip setpoint less conservative than the value shown in the Allowable Values column of Table 3.3-4, either adjust the trip setpoint to be consistent with the value specified in the Trip Setpoint column of Table 3.3-4 within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months or declare the channel inoperable and take the ACTION shown in Table 3.3-3.

b. With an engineered safety feature actuation system instru-mentation channel inoperable, take the ACTION shown in Table 3.3-3.

SURVEILLANCE REQUIREMENTS 4.3.2.1.1 Each engineered safety feature acutation system instrumen-tation 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 4.3-2.

4.3.2.1.2 The logic for the bypasses shall be demonstrated OPERABLE during the at power CHANNEL FUNCTIONAL TEST of channels affects by bypass operation. The total bypass function shall be demonstrated OPERABLE at least once per 18 months during CHANNEL CALIBRATION testing of each channel affected by bypass operation.

MILLSTONE - UNIT 2 3/4 3-9 Amendment No. 7JP,282 0811

INSTRUMENTATION SURVEILLANCE REQUIREMENTS (Continued) 4.3.2.1.3 The ENGINEERED SAFETY FEATURES RESPONSE TIME of each ESF function shall be demonstrated to be within the limit at least once per 18 months. Each test shall include at least one channel per function such that all channels are tested at least once every N times 18 months where N is the total number of redundant channels in a specific ESF function as shown in the "Total No. of Channels" Column of Table 3.3-3.

MILLSTONE - UNIT 2 3/4 3-10 Amendment No. fy, 77?, fp j2621 0811

lAnLt J.J-J ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION o =

MINIMUM TOTAL NO. CHANNELS CHANNELS APPL ICABLE 0 FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION

1. SAFETY INJECTION (SIAS) (d)

a. Manual (Trip Buttons) 2 I 2 1, 2, 3, 4 1

--I b. Containment Pressure -

High 4 2 3 1, 2, 3 2

c. Pressurizer Pressure -

Low 4 2 3 1, 2, 3(a) 2 di. Automatic Actuation Logic 2 I 2 1, 2, 3 5 I

2. CONTAINMENT SPRAY (CSAS)

a. Manual (Trip Buttons) 2 I 2 1, 2, 3, 4 1

b. Containment Pressure-High - High 4 2(b) 3 1, 2, 3 2

c. Automatic Actuation Logic 2 1 2 1, 2, 3 5 I

-P

3. CONTAINMENT ISOLATION (CIAS)

a. Manual CIAS (Trip Buttons) 2 I 2 1, 2, 3, 4 1

b. Manual SIAS (Trip Buttons) 2 2 1, 2, 3, 4 1

c. Containment Pressure -

=0 High 4 2 3 1, 2, 3 2

d. Pressurizer Pressure -

Low 4 2 3 1, 2, 3(a) 2 0, e. Automatic Actuation Logic 2 1 2 1, 2, 3 5 I

TABLE 3.3-3 (Continued)

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION o z MINIMUM TOTAL NO. CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION r,0I

4. MAIN STEAM LINE ISOLATION C

a. Manual MSI (Trip Buttons) 2 I 2 1, 2, 3, 4 1

--4 High

b. Containment Pressure-High 4 2 3 1, 2, 3 2

c. Steam Generator Pressure - Low 4 2 3 1, 2, 3(c) 2

d. Automatic Actuation Logic 2/Steam 1/Steam 2/Steam 1, 2, 3 5 Generator Generator Generator I

5. ENCLOSURE BUILDING FILTRATION (EBFAS)

Ca

a. Manual EBFAS (Trip 2 1 2 1, 2, 3, 4 1 I% Buttons)

b. Manual SIAS (Trip 2 1 2 1, 2, 3, 4 1 Buttons)

c. Containment Pressure-High 4 2 3 1, 2, 3 2 CD a

CD

d. Pressurizer Pressure-Low 4 2 3 1, 2, 3(a) 2 C+

e. Automatic Actuation Logic 2 1 2 1, 2, 3 5 I

6. CONTAINMENT SUMP RECIRCULATION (SRAS)

a. Manual SRAS (Trip Buttons) 2 1 2 1, 2, 3, 4 1 Zi "ta

b. Refueling Water Storage Tank - Low 4 2 3 1, 2, 3 4

c. Automatic Actuation Logic 2 1 2 1, 2, 3 5 1

o 3 TABLE 3.3-3 (Continued)

-r C-

-I ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION 0

MINIMUM C TOTAL NO. CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION

-I

7. DELETED

8. LOSS OF POWER

a. 4.16 kv Emergency Bus Undervoltage - level one 4/bus 2/Bus 3/bus 1, 2, 3 2

b. 4.16 kv Emergency Bus Undervoltage - level two 4/Bus 2/Bus 3/Bus 1, 2, 3 2 Ca) r1 to ED a

tin-r-'

- r-TABLE 3.3-3 (Continued)

F-CA FNaTNFFRFn "AFFTV FFATIIMF ArTUIATTAN YVSTFM TNIZTRIIMFNTATTnN

--I z olu

W11. - .n A lL^ AlS8zlzzL l1@BV o8nlSl r"

MINIMUM TOTAL NO. CHANNELS CHANNELS APPLICABLE z-I FUNCTIONAL UNIT OF CHANNELS TO TRIP C' OPERABLE MODES ACTION

9. AUXILIARY FEEDWATER

a. Manual I/pump 1/pump 1/pump 1, 2, 3 6 I

b. Steam Generator 4 2 3 1, 2, 3 Level - Low 2

c. Automatic Actuation Logic 2/Steam 1/Steam 2/Steam 1, 2, 3 5 Generator Generator Generator I

10. STEAM GENERATOR BLOWDOWN W

a. Steam Generator 4 2 3 1, 2, 3 2 w

Level - Low 30 M

ED

q 0

-p.4 8il

TABLE 3.3-3 (Continued)

TABLE NOTATION (a) Trip function may be bypassed when pressurizer pressure is < 1850 psia; bypass shall be automatically removed when pressurizer pressure is > 1850 psia.

(b) An SIAS signal is first necessary to enable CSAS logic.

(c) Trip function may be bypassed when steam generator pressure is < 700 psia; bypass shall be automatically removed when steam generator pressure is >

700 psia.

(d) In MODE 4 the HPSI pumps are not required to start automatically on a SIAS.

(e) DELETED ACTION STATEMENTS ACTION 1 - With the number of OPERABLE channels one less than the Total Number of Channels, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in COLD SHUTDOWN within the next 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

ACTION 2 - With the number of OPERABLE channels one less than the Total Number of Channels, operation may continue provided the following conditions are satisfied:

a. The inoperable channel is placed in either the bypassed or tripped condition within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months . The inoperable channel shall either be restored to OPERABLE status, or placed in the tripped condition, within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months .

b. Within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months , all functional units receiving an input from the inoperable channel are also declared inoperable, and the appropriate actions are taken for the affected functional units.

c. The Minimum Channels OPERABLE requirement is met; however, one additional channel may be removed from service for up to 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months , provided one of the inoperable channels is placed in the tripped condition.

MILLSTONE - UNIT 2 3/4 3-15 Amendment No. jfp, 779, 71i, M, I 0811 ZW, 777, 7?0, 282

TABLE 3.3-3 (Continued)

ACTION 3 - DELETED ACTION 4 - With the number of OPERABLE channels one less than the Total Number of Channels and with the pressurizer pressure:

a. < 1850 psia: immediately place the inoperable channel in the bypassed condition; restore the inoperable channel to OPERABLE status prior to increasing the pressurizer pressure above 1850 psia.

b. > 1850 psia, operation may continue with the inoperable channel in the bypassed condition, provided the following condition is satisfied:

1. The Minimum Channels OPERABLE requirement is met; however, one additional channel may be removed from service for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing per Specification 4.3.2.1.1 provided BOTH of the inoperable channels are placed in the bypassed condition.

ACTION 5 - With the number of OPERABLE channels one less than the Total Number of Channels, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in at least HOT SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

ACTION 6 - With the number of OPERABLE channels one less than the Total Number of Channels, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-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 .

MILLSTONE - UNIT 2 3/4 3-16 Amendment No. Iff, 77Y, Afi, 7fF, I 0811 11y. Ify, 282

TABLE 3.3-4 ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION TRIP VALUES ALLOWABLE

" , FUNCTIONAL UNIT TRIP SETPOINT VALUES

< 1. SAFETY INJECTION (SIAS) rn a. Manual (Trip Buttons) Not Applicable Not Applicable

b. Containment Pressure - High < 4.42 psig < 5.07 psig z

-' c. Pressurizer Pressure - Low > 1714 psia > 1704 psia

d. Automatic Actuation Logic Not Applicable Not Applicable I

2. CONTAINMENT SPRAY (CSAS)

a. Manual (Trip Buttons) Not Applicable Not Applicable

b. Containment Pressure -- High-High < 9.48 psig < 10.11 psig

c. Automatic Actuation Logic Not Applicable Not Applicable I

~ 3. CONTAINMENT ISOLATION (CIAS)

a. Manual CIAS (Trip Buttons) Not Applicable Not Applicable

b. Manual SIAS (Trip Buttons) Not Applicable Not Applicable

c. Containment Pressure - High < 4.42 psig < 5.07 psig id d. Pressurizer Pressure - Low > 1714 psia > 1704 psia

e. Automatic Actuation Logic Not Applicable Not Applicable I e 4. MAIN STEAM LINE ISOLATION

a. Manual (Trip Buttons) Not Applicable Not Applicable

b. Containment Pressure - High < 4.42 psig c 5.07 psig

c. Steam Generator Pressure - Low > 572 psia > 558 psia

d. Automatic Actuation Logic Not Applicable Not Applicable I

MDLt g.J-4 (Continued)

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION TRIP VALUES ALLOWABLE FUNCTIONAL UNIT TRIP SETPOINT VALUES wo r-=

I-CA,

5. ENCLOSURE BUILDING FILTRATION (EBFAS)

-- I 2

a. Manual EBFAS (Trip Buttons) Not Applicable Not Applicable c b. Manual SIAS (Trip Buttons) Not Applicable Not Applicable

c. Containment Pressure - High < 4.42 psig < 5.07 psig z d. Pressurizer Pressure - Low 2 1714 psia > 1704 psia

--I e. Automatic Actuation Logic Not Applicable Not Applicable I r4)

6. CONTAINMENT SUMP RECIRCULATION (SRAS)

a. Manual SRAS (Trip Buttons) Not Applicable Not Applicable

b. Refueling Water Storage Tank -Low 46 + 3 inches above 46 + 6 inches tank bottom above tank bottom

c. Automatic Actuation Logic Not Applicable Not Applicable I

7. DELETED

(-a at Z W0.

" zo Ii I?

TABLE 3.3-4 (Continued) rNTmFFRFn oszzu>l^ov AFFTV PFATIIDF ATIATTnN 1 X

-rc onvs vivlv .- I YVZTFM TN4TDIIMIFNTATTAN

-11 slr ~ uilu TDTD VA IIFcZ prior

- r&v$

ALLOWABLE C FUNCTIONAL UNIT TRIP SETPOINT VALUES

--I z0 8. LOSS OF POWER M a. 4.16 kv Emergency Bus Undervoltage - > 2912 volts with a > 2877 volts with a level one 2.0 + 0.1 second time 2.0 + 0.1 second time delay delay

b. 4.16 kv Emergency Bus Undervoltage - 2 3700 volts with > 3663 volts with level two an 8.0 +2.O second an 8.0 +/- 2.0 second time delay time delay

9. AUXILIARY FEEDWATER

-0 W

a. Manual Not Applicable Not Applicable 4%

b. Steam Generator Level - Low > 26.8% > 25.2%

c. Automatic Actuation Logic Not Applicable Not Applicable I

10. STEAM GENERATOR BLOWDOWN

a. Steam Generator Level - Low > 26.8% > 25.2%

o' .49 I.W

TABLE 4.3-2 ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION SURVEILLANCE REQUIREMENTS 0 3 r- CHANNEL MODES IN WHICH

_ CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE 01 FUNCTIONAL UNIT CHECK CALIBRATION TEST REQUIRED

1. SAFETY INJECTION (SIAS)

a. Manual (Trip Buttons) N.A. N.A. R N. A.

b. Containment Pressure - High S R M 1, 2, 3

c. Pressurizer Pressure - Low S R M 1, 2, 3

d. Automatic Actuation Logic N.A. N.A. M(1) 1, 2, 3

2. CONTAINMENT SPRAY (CSAS)

a. Manual (Trip Buttons) N.A. N.A. R N.A.

b. Containment Pressure--

High - High S R M 1, 2, 3

c. Automatic Actuation Logic N.A. N.A. M(1) 1, 2, 3

3. CONTAINMENT ISOLATION (CIAS)

a. Manual CIAS (Trip Buttons) N.A. N.A. R N.A.

b. Manual SIAS (Trip Buttons) N.A. N.A. R N.A.

c. Containment Pressure - High S R M 1, 2, 3

d. Pressurizer Pressure - Low S R M 1, 2, 3

e. Automatic Actuation Logic N.A. N.A. M(1) 1, 2, 3

4. MAIN STEAM LINE ISOLATION

a. Manual (Trip Buttons) N.A. N.A. R N.A.

b. Containment Pressure - High S R M 1, 2, 3

c. Steam Generator Pressure - Low S R M 1, 2, 3

d. Automatic Actuation Logic N.A. N.A. M(1) 1, 2, 3

5. ENCLOSURE BUILDING FILTRATION (EBFAS)

a. Manual EBFAS (Trip Buttons) N.A. N.A. R N.A.

b. Manual SIAS (Trip Buttons) N.A. N.A. R N.A.

c. Containment Pressure - High S R M 1, 2, 3

d. Pressurizer Pressure - Low S R M 1, 2, 3

e. Automatic Actuation Logic N.A. N.A. M(1) 1, 2, 3 No

TABLE 4.3-2 (Continued)

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION SURVEILLANCE REQUIREMENTS 0 _

CHANNEL MODES IN WHICH CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST REQUIRED

6. CONTAINMENT SUMP RECIRCULATION (SRAS)

-l

a. Manual SRAS (Trip Buttons) N.A. N.A. R N.A.

b. Refueling Water Storage Tank - Low S R M 1, 2, 3

c. Automatic Actuation Logic N.A. N.A. M(1) 1, 2, 3

7. DELETED

8. LOSS OF POWER

a. 4.16 kv Emergency Bus Undervoltage - level one S R M 1, 2, 3

b. 4.16 kv Emergency Bus Undervoltage - level two S R M 1, 2, 3

9. AUXILIARY FEEDWATER

a. Manual N.A. N.A. R N.A.

b. Steam Generator Level - Low S R M 1, 2, 3 C. Automatic Actuation Logic N.A. N.A. M 1, 2, 3

10. STEAM GENERATOR BLOWDOWN

a. Steam Generator Level - Low S R

.. M 1. 2. 3-1

TABLE 4.3-2 (Continued)

TABLE NOTATION (1) The coincident logic circuits shall be tested automatically or manually at least once per 31 days. The automatic test feature shall be verified OPERABLE at least once per 31 days. The provisions of Specification 4.0.4 are not applicable for entry into MODE 3 or other specified conditions for surveillance testing of the following:

a. Pressurizer Pressure Safety Injection Automatic Actuation Logic; and

b. Pressurizer Pressure Containment Isolation Automatic Actuation Logic; and

c. Steam Generator Pressure Main Ste,am Line Isolation Automatic Actuation Logic; and

d. Pressurizer Pressure Enclosure Building Filtration Automatic Actuation Logic.

Testing of the automatic actuation logic for Pressurizer Pressure Safety Injection, Pressurizer Pressure Containment Isolation, and Pressurizer Pressure Enclosure Building Filtration shall be performed within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after exceeding a pressurizer pressure of 1850 psia in MODE 3. Testing of the automatic actuation logic for Steam Generator Pressure Main Steam Line Isolation shall be performed within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after exceeding a steam generator pressure of 700 psia in MODE 3.

MILLSTONE - UNIT 2 3/4 3-22 Amendment No. 97, Ms 1 0811 282

INSTRUMENTATION ENGINEERED SAFETY FEATURE ACTUATION SYSTEM SENSOR CABINET POWER SUPPLY DRAWERS LIMITING CONDITION FOR OPERATION 3.3.2.2 The engineered safety feature actuation system Sensor Cabinets (RC02A1, RC02B2, RCO2C3 & RC02D4) Power Supply Drawers shall be OPERABLE and energized from the normal power source with the backup power source available.

The normal and backup power sources for each sensor cabinet is detailed in Table 3.3-5a:

CABINET NORMAL POWER BACKUP POWER RCO2A1 VA-10 VA-40 RC02B2 VA-20 VA-30 RCO2C3 VA-30 VA-20 RC02D4 VA-40 VA-10 Table 3.3-5a APPLICABILITY: MODES 1, 2, 3 and 4 ACTION:

With any of the Sensor Cabinet Power Supply Drawers inoperable, or either the normal or backup power source not available as delineated in Table 3.3-5a, restore the inoperable Sensor Cabinet Power Supply Drawer to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in COLD SHUTDOWN within the next 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

SURVEILLANCE REQUIREMENTS 4.3.2.2.1 The engineered safety feature actuation system Sensor Cabinet Power Supply Drawers shall be determined OPERABLE once per shift by visual inspection of the power supply drawer indicating lamps.

4.3.2.2.2 Verify the operability of the Sensor Cabinet Power Supply auctioneering circuit at least one per 18 months.

MILLSTONE - UNIT 2 3/4 3-23 Amendment No. 7Y,2821 0811

INSTRUMENTATION 3/4.3.3 MONITORING INSTRUMENTATION RADIATION MONITORING 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 alarm/trip setpoint exceeding the value shown in Table 3.3-6, adjust the setpoint to within the limit within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 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 Specification 3.0.3 are not applicable.

SURVEILLANCE REQUIREMENTS 4.3.3.1.1 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.

4.3.3.1.2 The trip value shall be such that the containment purge effluent shall not result in calculated concentrations of radioactivity offsite in excess of 10 CFR Part 20, Appendix B Table II. For the purposes of calculating this trip value, a x/Q = 5.8 x 10.8 sec/rM3 shall be used when the system is aligned to purge through the building vent and a x/Q = 7.5 x 10-8 sec/M 3 shall be used when the system is aligned to purge through the Unit 1 stack, the gaseous and particulate (Half Lives greater than 8 days) radioactivity shall be assumed to be Xe-133 and Cs-137, respectively. However, the setpoints shall be no greater than 5 x10 5 cpm.

4.3.3.1.3 Verify the response time of the control room isolation channel at least once per 18 months.

MILLSTONE - UNIT 2 3/4 3-24 Amendment No. 7LO,f,282 I 0811

RADIATION MONITORING INSTRUMENTATION o = MINIMUM

,r CHANNELS APPLICABLE ALARM/TRIP MEASUREMENT

- INSTRUMENT OPERABLE MODES SETPOINT RANGE ACTION 0

1. AREA MONITORS

-I a. Spent Fuel Storage and Ventilation

100 mR/hr 1 10+4 mR/hr 13 2 -

rt) System Isolation

b. Control Room Isolation 1 ALL MODES 2 mR/hr 10.1 - 104 mR/hr 16

c. Containment High Range I 1,2,3, &4 100 R/hr 10 - 108 R/hr 17 I

2. PROCESS MONITORS

a. Containment 1 ALL MODES** the value 10 - 10 +6 cpm 14 Atmosphere-Particulate determined in W accordance with M specification 4.3.3.1.2 (A

en

b. Containment 1 ALL MODES** the value 10 - 10+6 cpm 14 Atmosphere-Gaseous determined in accordance with Specification 4.3.3.1.2 93

c. Noble Gas Effluent 1 1,2,3, &4 2 x 10-1 uci/cc 10-3 105 uci/cc 17 It 3 Monitor (high range)

(Unit 2 stack)

W__

O

With fuel in storage building.

'- **These radiation monitors are not required to be operable during Type "A" Integrated Leak Rate testing.

a CD 94 11s

TABLE 3.3-6 (Continued)

TABLE NOTATION (a) DELETED ACTION 13 - With the number of area monitors OPERABLE less than required by the MINIMUM CHANNELS OPERABLE requirement, perform area surveys of the monitored area with portable monitoring instrumentation at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

ACTION 14 - With the number of process monitors OPERABLE less than required by the MINIMUM CHANNELS OPERABLE requirement either (a) obtain and analyze grab samples of the monitored parameter at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , or (b) use a Constant Air Monitor to monitor the parameter.

ACTION 15 - DELETED ACTION 16 - With the number of OPERABLE channels less than required by the MINIMUM CHANNELS OPERABLE requirement, within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months initiate and maintain operation, of the control room emergency ventilation system in the recirculation mode of operation.

ACTION 17 - With the number of OPERABLE channels less than required by the MINIMUM CHANNELS OPERABLE requirements, initiate the preplanned alternate method of monitoring the appropriate 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 discovery or

2) prepare and submit a Special Report to the Commission pursuant to Specification 6.9.2 within 14 days following discovery outlining the action taken, the cause of the inoperability and the plans and schedule for restoring the system to OPERABLE status.

MILLSTONE - UNIT 2 3/4 3-26 Amendment Nos. ?P, I??, )7?, I 0811 If,282

o 2C TABLE 4.3-3 RADIATION MONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTS 0

Il CHANNEL MODES IN WHICH CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE INSTRUMENT CHECK CALIBRATION TEST REQUIRED

-I4 PO 1. AREA MONITORS

a. Spent Fuel Storage Ventilation System Isolation S R M *

b. Control Room Isolation S R M ALL MODES

c. Containment High Range S M 1, 2, 3, & 4 I

1-

2. PROCESS MONITORS

a. Containment Atmosphere-Particulate S R M ALL MODES

_, b. Containment Atmosphere-W Gaseous S R M ALL MODES To

c. Noble Gas Effluent S R M 1, 2, 3, & 4 I Monitor (high range)

N i (Unit 2 Stack)

4 2

uL M

With fuel in storage building

- Calibration of the sensor with a radioactive source need only be performed on the lowest range. Higher ranges may be calibrated electronically.

INSTRUMENTATION REMOTE SHUTDOWN INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.3.5 The remote shutdown monitoring instrumentation channels shown in Table 3.3-9 shall be OPERABLE with readouts displayed external to the control room.

APPLICABILITY: MODES 1, 2 and 3.

ACTION:

With the number of OPERABLE remote shutdown moitoring instrumentation channels less than required by Table 3.3-9, either: I

a. Restore the inoperable channel to OPERABLE status within 7 days, or

b. Be in HOT SHUTDOWN within the next 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

SURVEILLANCE REQUIREMENTS 4.3.3.5 Each remote shutdown monitoring instrumentation channel shall be demonstrated OPERABLE by performance of the CHANNEL CHECK and CHANNEL CALIBRATION operations at the frequencies shown in Table 4.3-6.

MILLSTONE - UNIT 2 3/4 3-28 Amendment Ho.281 0811

o z TABLE 3.3-9 I- SHUTDOWN MONITORING INSTRUMENTATION r

cn MINIMUM READOUT MEASUREMENT CHANNELS I INSTRUMENT LOCATION RANGE OPERABLE M 1. Wide Range Logarithmic Neutron Flux Hot Shutdown Panel 10-.8% - 100% 1 Monitor (C-21)

2. Reactor Trip Breaker Indication Reactor Trip OPEN-CLOSE 1/trip breaker Switchgear (Q03)

3. Reactor Cold Leg Temperature Hot Shutdown Panel 0-600OF 1 (C-21)

4. Pressurizer Pressure Hot Shutdown Panel W a. Low Range (C-21) 0-1600 psia 1

b. High Range 1500-2500 psia 1 ra)

IV 1

5. Pressurizer Level Hot Shutdown Panel 0-100%

(C-21)

6. Steam Generator Pressure Hot Shutdown Panel 0-1200 psia 1/steam generator (C-21)

7. Steam Generator Level Hot Shutdown Panel 0-100% 1/steam generator (C-21 9

to tD 0.

El co

TABLE 4.3-6 0!

- I- REMOTE SHUTDOWN MONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTS U,

-I CHANNEL CHANNEL INSTRUMENT -CHECK CALIBRATION

1. Wide Range Logarithmic M R*

-I Neutron Flux

2. Reactor Trip Breaker M N.A.

Indication

3. Reactor Cold Leg Temperature M R

4. Pressurizer Pressure

a. Low Range N R

b. High Range N R W 5. Pressurizer Level N R

6. Steam Generator Level M R Ca CD) 7. Steam Generator Pressure N R 3

Neutron detectors are excluded from the CHANNEL CALIBRATION.

.It N

INSTALLATION ACCIDENT MONITORING LIMITING CONDITION FOR OPERATION 3.3.3.8 The accident monitoring instrumentaiton channels shown in Table 3.3-11 shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTION:

a. Actions per Table 3.3-11.

SURVEILLANCE REQUIREMENTS 4.3.3.8 Each accident monitoring instrumentation channel shall be demonstrated OPERABLE by performance of the CHANNEL CHECK and CHANNEL CALIBRATION operations at the frequencies shown in Table 4.3-7.

MILLSTONE - UNIT 2 3/4 3-31 Amendment No. ff, 7y7,282 0811

IMLL J.-11 ACCIDENT MONITORING INSTRUMENTATION o3 en .

Minimum I- Total No. Channels CA

_I Instrument of Channels Ooerable Action z 1. Pressurizer Water Level 2 I 1 C

2. Auxiliary Feedwater Flow Rate 2/S.G. 1/S. G. 1

-4 N 3. RCS Subcooled/Superheat Monitor 2 1 2

4. PORV Position Indicator Acoustic Monitor 1/valve 1/valve 3

5. PORV Block Valve Position Indicator 1/valve 1/valve 3

6. Safety Valve Position Indicator Acoustic Monitor 1/valve 1/val ve 3

7. Containment Pressure (Wide Range) 2- 1 4 I C 8. Containment Water Level (Narrow Range) 1 1 7##

9. Containment Water Level (Wide Range) 2 1 4

10. Core Exit Thermocouples 4 CETs/core quadrant 2 CETs in any 5 M of 2 core quadrants

11. Main Steam Line Radiation Monitor 3 3 6 CL

12. Reactor Vessel Coolant Level 2* 1* 8 OF 9+

A channel is eight (8) sensors in a probe. A channel is operable if four (4) or more sensors, two (2) or more in the upper four and two (2) or more in the lower four, are operable.

1. Refer to ACTION statement in Technical Specification 3.4.6.1.

zm

-4 r1

TABLE 3.3-11 (Continued)

ACTION STATEMENTS ACTION 1 - With the number of OPERABLE channels less than the MINIMUM CHANNELS OPERABLE requirements of Table 3.3-11, either restore the inoperable channel(s) to OPERABLE status within 30 days or be in HOT STANDBY within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

ACTION 2 - With the number of channels OPERABLE less than the MINIMUM CHANNELS OPERABLE, determine the subcooling margin once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

ACTION 3 - With any individual valve position indicator inoperable, obtain quench tank temperature, level and pressure information, and monitor discharge pipe temperature once per shift to determine valve position. This action is not required if the PORV block valve is closed with power removed in accordance with Specification 3.4.3.a or 3.4.3.b.

ACTION 4 - a. With the number of OPERABLE accident monitoring instrumentation channels less than the total number of channels shown in Table 3.3-11, restore the inoperable channel(s) to OPERABLE status within 7 days, or submit a special report to the Commission pursuant to Specification 6.9.2 within the next 10 days outlining the cause of the malfunction, the plans for restoring the channel(s) to OPERABLE status, and any alternate methods in affect for estimating the applicable parameter during the interim.

b. With the number of OPERABLE accident monitoring instrumentation channels less than the MINIMUM CHANNELS OPERABLE requirements of Table 3.3-11, restore the inoperable channel(s) to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months , or submit a special report to the Commission pursuant to Specification 6.9.2 within the next 10 days outlining the cause of the malfunction, the plans for restoring the channel(s) to OPERABLE status, and any alternate methods in affect for estimating the applicable parameter during the interim.

MILLSTONE - UNIT 2 3/4 3-33 Amendment No. jgp, 0811 ' 282

ACTION 5 - With the number of OPERABLE accident monitoring instrumentation channels less than the MINIMUM CHANNELS OPERABLE requirements of Table 3.3-11, restore the inoperable channel(s) to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months , or begin at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

ACTION 6 - With any channel of radiation monitoring instrumentation inoperable, portable hand-held radiation detection equipment will be used to assess radiation releases from the atmospheric dump valves and steam generator safeties subsequent to a steam generator tube rupture.

ACTION 7 - Restore the inoperable system to OPERABLE status within 7 days or be in COLD SHUTDOWN within the next 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . (See the ACTION statement in Technical Specification 3.4.6.1.).

ACTION 8 - With the number of OPERABLE Channels one less than the MINIMUM CHANNELS OPERABLE in Table 3.3-11, either restore the inoperable channel(s) to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months if repairs are feasible without shutting down or:

1. Prepare and submit a Special Report to the Commission pursuant to Specification 6.9.2 within 30 days following the event outlining the action taken, the cause of the inoperability and the plans and schedule for restoring the system to OPERABLE status; and

2. Restore the system to OPERABLE status at the next scheduled refueling; and

3. Initiate an alternate method of monitoring the Reactor Vessel inventory.

MILLSTONE - UNIT 2 3/4 3-34 Amendment No. II?, 7f?,282 I 0811

TABLE 4.3-7

_ r ACCIDENT MONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTS I-Cn I

CHANNEL CHANNEL INSTRUMENT CHECK CALIBRATION

1. Pressurizer Water Level M R

-I

2. Auxiliary Feedwater Flow Rate M R

3. Reactor Coolant System Subcooled/Superheat Monitor M R

4. PORV Position Indicator (Acoustic Monitor) M R

5. PORV Block Valve Position Indicator N.A. R 0 6. Safety Valve Position Indicator (Acoustic Monitor) M R C&)

7. Containment Pressure M R Can Co

8. Containment Water Level (Narrow Range) M R

9. Containment Water Level (Wide Range) M R w

10. Core Exit Thermocouples M R*

11. Main Steam Line Radiation Monitor M R a.

12. Reactor Vessel Coolant Level M R*

Electronic calibration from the ICC cabinets only.

0 410%

.rof ull CONTAINMENT PURGE VALVE ISOLATION SIGNAL LIMITING CONDITION FOR OPERATION 3.3.4 One Containment Purge Valve Isolation Signal containment gaseous radiation monitor channel, one Containment Purge Valve Isolation Signal containment particulate radiation monitor channel, and one Containment Purge Valve Isolation Signal automation logic train shall be OPERABLE.

APPLICABILITY: During CORE ALTERATIONS with the containment purge valves open.

During the movement of irradiated fuel assemblies inside containment with the containment purge valves open.

ACTION:

a. With no OPERABLE Containment Purge Valve Isolation Signal containment gaseous radiation monitor channel, immediately suspend CORE ALTERATIONS and the movement of irradiated fuel assemblies inside containment, or immediately place and maintain the containment purge valves in the closed position. Enter applicable conditions and required ACTIONS for the affected valves of Technical Specification 3.9.4, "Containment Penetrations."

b. With no OPERABLE Containment Purge Valve Isolation Signal containment particulate radiation monitor channel, immediately suspend CORE ALTERATIONS and the movement of irradiated fuel assemblies inside containment, or immediately place and maintain the containment purge valves in the closed position. Enter applicable conditions and required ACTIONS for the affected valves of Technical Specification 3.9.4, "Containment Penetrations."

c. With no OPERABLE Containment Purge Valve Isolation Signal automatic actuation logic train, immediately suspend CORE ALTERATIONS and the movement of irradiated fuel assemblies inside containment, or immediately place and maintain the containment purge valves in the closed position. Enter applicable conditions and required ACTIONS for the affected valves of Technical Specification 3.9.4, "Containment Penetrations."

SURVEILLANCE REQUIREMENTS 4.3.4.1 Perform a CHANNEL CHECK on each Containment Purge Valve Isolation Signal containment gaseous and particulate radiation monitor channel at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

4.3.4.2 Perform a CHANNEL FUNCTIONAL TEST on each Containment Purge Valve Isolation Signal containment gaseous and particulate radiation monitor channel at least once per 31 days.

MILLSTONE UNIT NO. 2 3/4 3-36 Amendment No. ZM,282 0811

SURVEILLANCE REQUIREMENTS 4.3.4.3 Perform a CHANNEL FUNCTIONAL TEST on each Containment Purge Valve Isolation Signal automatic actuation logic train at least once per 31 days. This actuation logic shall include verification of the proper operation of the actuation relay.

4.3.4.4 Perform a CHANNEL CALIBRATION on each Containment Purge Valve Isolation Signal containment gaseous and particulate radiation monitor channel at least once per 18 months.

4.3.4.5 Verify Containment Purge Valve Isolation Signal response time at least once per 18 months. Each test shall include at least one containment gaseous and one containment particulate radiation monitor channel such that all channels are tested at least once every N times 18 months where N is the total number of containment gaseous or total number of containment particulate radiation monitor channels.

MILLSTONE UNIT NO. 2 3/4 3-37 Amendment No. Zip,282 0811

LIMITING SAFETY SYSTEM SETTINGS BASES Thermal Margin/Low Pressure (Continued)

The trip is initiated whenever the reactor coolant system pressure signal drops below either 1865 psia or a computed value as described below, whichever is higher. The computed value is a function of the higher of AT power or neutron power, reactor inlet temperature, the number of reactor coolant pumps operating and the AXIAL SHAPE INDEX. The minimum value of reactor coolant flow rate, the maximum AZIMUTHAL POWER TILT and the maximum CEA deviation permitted for continuous operation are assumed in the generation of this trip function.

In addition, CEA group sequencing in accordance with Specifications 3.1.3.5 and 3.1.3.6 is assumed. Finally, the maximum insertion of CEA banks which can occur during any anticipated operational occurrence prior to a Power Level-High trip is assumed.

Thermal Margin/Low Pressure trip setpoints are derived from the core safety limits. A safety margin is provided which includes allowances for equipment response times, core power, RCS temperature, and pressurizer pressure measurement uncertainties, processing errors, and a further allowance to compensate for the time delay associated with providing effective termination of the occurrence that exhibits the most rapid decrease in margin to the safety limit.

Loss of Turbine A Loss of Turbine trip causes a direct reactor trip when operating above 15% of RATED THERMAL POWER as sensed by the power range nuclear instrument Level 1 bistable. This trip provides turbine protection, reduces the severity of the ensuring transient and helps avoid the lifting of the main steam line safety valves during the ensuing transient, thus extending the service life of these valves. No credit was taken in the accident analyses for operation of this trip. Its functional capability at the specified trip setting is required to enhance the overall reliability of the Reactor Protection System.

The Wide Range Logarithmic Neutron Flux Monitor - Shutdown, Reactor Protection System Logic Matrices, Reactor Protection System Logic Matrix Relays, and Reactor Trip Breakers functional units are components of the Reactor Protective System for which OPERABILITY requirements are provided within the Technical Specifications (see Technical Specification 3.3.1.1, "Reactor Protective Instrumentation"). These functional units do not have specific trip setpoints or allowable values, similar to the manual reactor trip functional unit. However, these functional units are provided here for completeness and consistency with the RPS Instrumentation identified in Technical Specification 3.3.1.1.

MILLSTONE - UNIT 2 B 2-7 Amendment No. g, fl, Aid, IfZ, 0829 1nt, gag. 282

LIMITING SAFETY SYSTEM SETTINGS DELETED MILLSTONE - UNIT 2 B 2-8 Amendment No. 11, P19 lly,282

a1*.. INSTRUMENTATION BASES 3/4.3.1 AND 3/4.3.2 PROTECTIVE AND ENGINEERED SAFETY FEATURES (ESF) 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 combination thereof 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.

The OPERABILITY of these systems is required to provide the overall reliability, redundance and diversity assumed available in the facility design for the protection and mitigation of accident and transient conditions. The integrated operation of each of these systems is consistent with the assumptions used in the accident analyses.

Action Statement 2 of Tables 3.3-1 and 3.3-3 requires an inoperable Reactor Protection System (RPS) or Engineered Safety Feature Actuation.System (ESFAS) channel to be placed in the bypassed or tripped condition within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months . The inoperable channel may remain in the bypassed condition for a maximum of 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months . While in the bypassed condition, the affected functional unit trip coincidence will be 2 out of 3. After 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months , the channel must either be declared OPERABLE, or placed in the tripped condition. If the channel is placed in the tripped condition, the affected functional unit trip coincidence will become 1 out of 3. One additional channel may be removed from service for up to 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months , provided one of the inoperable channels is placed in the tripped condition.

Plant operation with an inoperable pressurizer high pressure reactor protection channel in the tripped condition is restricted because of the potential inadvertent opening of both pressurizer power operated relief valves (PORVs) if a second pressurizer high pressure reactor protection channel failed while the first channel was in the tripped condition. This plant operating restriction is contained in the Technical Requirements Manual.

The reactor trip switchgear consists of eight reactor trip circuit breakers, which are operated in four sets of two breakers (four channels). Each of the four trip legs consists of two reactor trip circuit breakers in series. The two reactor trip circuit breakers within a trip leg are actuated by separate initiation circuits. For example, if a breaker receives an open signal in trip leg A, an identical breaker in trip leg B will also receive an open signal. This arrangement ensures that power is interrupted to both Control Element Drive Mechanism buses, thus preventing a trip of only half of the control element assemblies (a half trip). Any one inoperable breaker in a channel will make the entire channel inoperable.

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 performed at the minimum frequencies are sufficient to demonstrate this capability.

The surveillance testing verifies OPERABILITY of the RPS by overlap testing of the four interconnected modules: measurement channels, bistable trip units, RPS logic, and reactor trip circuit breakers. When testing the measurement channels or bistable trip units that provide an automtic reactor trip function, the associated RPS channel will be removed from service, MILLSTONE - UNIT 2 B 3/4 3-1 Amendment No. I7f, J99, Zg Z 0813 282

,.., INSTRUMENTATION BASES 3/4.3.1 AND 3/4.3.2 PROTECTIVE AND ENGINEERED SAFETY FEATURES (ESF) INSTRUMENTATION (continued) declared inoperable, and Action Statememt 2 of the Technical Specification 3.3.1.1 entered. When testing the RPS logic (matrix testing), the individual RPS channels will not be affected. Each parameter within each RPS channel supplies three contacts to make up the 6 different logic ladders/ matrices (AB, AC, AD, BC, BD, and CD). During matrix testing, only one logic matrix is tested at a time. Since each RPS channel supplies 3 different logic ladders, testing one ladder matrix at a time will not remove an RPS channel from the overall logic matrix. Therefore, matrix testing will not remove an RPS channel from service or make the RPS channel inoperable. It is not necessary to enter an action statement while performing matrix testing. This also applies when testing the reactor trip circuit breakers since this test will not remove an RPS channel from service or make the RPS channel inoperable.

The ESFAS includes four sensor subsystems and two actuation subsystems for each of the functional units identified in Table 3.3-3. Each sensor subsystem includes measurement channels and bistable trip units. Each of the four sensor subsystem channels monitors redundant and independent process measurement channels. Each sensor is monitored by at least one bistable. The bistable associated with each ESFAS Function will trip when the monitored variable exceeds the trip setpoint. When tripped, the sensor subsystems provide outputs to the two actuation subsystems.

The two independent actuation subsystems each compare the four associated sensor subsystem outputs. If a trip occurs in two or more sensor subsystem channels, the two-out-of-four automatic actuation logic will initiate one train of ESFAS. An Automatic Test Inserter (ATI), for which the automatic actuation logic operability requirements of this specification do not apply, provides automatic test capability for both the sensor subsystems and the actuation subsystems.

The provisions of Specification 4.0.4 are not applicable for the CHANNEL FUNCTIONAL TEST of the Engineered Safety Feature Actuation System automatic actuation logic associated with Pressurizer Pressure Safety Injection, Pressurizer Pressure Containment Isolation, Steam Generator Pressure Main Steam Line Isolation, and Pressurizer Pressure Enclosure Building Filtration for entry into MODE 3 or other specified conditions. After entering MODE 3, Pressurizer pressure and steam generator pressure will be increased and the blocks of the ESF actuations on low pressurizer pressure and low steam generator Pressure will be automatically removed. After the blocks have been removed, the CHANNEL FUNCTIONAL TEST of the ESF automatic actuation logic can be performed. The CHANNEL FUNCTIONAL TEST of the ESF automatic actuation logic must be performed within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after establishing the appropriate plant conditions, and prior to entry into MODE 2.

The measurement of response time at the specified frequencies provides 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. The Reactor Protective and Engineered Safety Feature response times are contained in the Millstone Unit No. 2 Technical Requirements Manual. Changes to the Technical Requirements Manual require a 10CFR50.59 review as well as a review by the Plant Operations Review Committee.

MILLSTONE - UNIT 2 B 3/4 3-1a Amendment No. gy, gX, If, 282 0813

I ~~ ~ ~ ~ ~

3/4.3.3 MONITORING INSTRUMENTATION 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 by the individual channels and 2) the alarm or automatic action is initiated when the radiation level trip setpoint is exceeded.

The analysis for a Steam Generator Tube Rupture Event and for a Millstone Unit No. 3 Loss of Coolant Accident credits the control room ventilation inlet duct radiation monitors with closure of the Unit 2 control room isolation dampers. In the event of a single failure in either channel (1 per train), the control room isolation dampers automatically close. The response time test for the control room isolation dampers includes signal generation time and damper closure. The response time for the control isolation dampers is maintained within the applicable facility surveillance procedure.

The spent fuel storage area monitors provide a signal to direct the ventilation exhaust from the spent fuel storage area through a filter train when the dose rate exceeds the setpoint. The filter train is provided to reduce the particulate and iodine radioactivity released to the atmosphere.

However, neither the analysis of a fuel handling accident or the analysis of a spent fuel cask drop accident in the spent fuel storage area credit automatic diversion of the spent fuel storage area ventilation exhaust through an enclosure building filtration train for accident mitigation.

The spent fuel storage area radiation monitors will detect an increase in radiation levels due to a lowering of spent fuel pool water level. This will provide additional indication to the plant operators of an unexpected decrease in spent fuel pool water level.

The containment airborne radiation monitors (gaseous and particulate) provide early indication of leakage from the Reactor Coolant System as specified in Technical Specification 3.4.6.1. In addition, these radiation monitors will initiate automatic closure of the containment purge valves upon detection of high airborne radioactivity levels inside containment. The requirements for the automatic closure of the containment purge valves is addressed by Technical Specification 3.3.4 The maximum allowable trip value for these monitors corresponds to calculated concentrations at the site boundary which would not exceed the concentrations listed in 10 CFR Part 20, Appendix B, Table II. Exposure for a year to the concentrations in 10 CFR Part 20, Appendix B. Table corresponds to a total body dose to an individual of 500 mrem which iswell below the guidelines of 10 CFR Part 100 for an individual at any point on the exclusion area boundary for two hours.

Determination of the monitor's trip value in counts per minute, which is the actual instrument response, involves several factors including: 1) the atmospheric dispersion x/Q), 2) isotopic com osition of the sample, 3) sample flow rate, 4) sample co lection efficiency, 5) counting efficiency, and 6) the background radiation level at the detector. The x/Q of 5.8 x 10-8 sec/M 3 is the highest annual average x/Q estimated for the site boundary (0.48 miles in the NE sector) for vent releases from the containment and 7.5 xlO-8 sec/M 3 is the highest annual average x/Q estimated for an off-site location (3miles in the NNE sector) for releases from the Unit I stack. This calculation also assumes that the isotopic composition is xenon-133 for gaseous radioactivity and cesium-137 for particulate radioactivity (Half Lives greater than 8 days). The upper limit of xIO cpm is approximately 90 percent of full instrument scale.

MILLSTONE - UNIT 2 B 3/4 3-2a Amendment No. 7, 7, gg, 0814 thy th, 282

v t e Letter Sequence Other
TAC:MB5008, (Open)
Initiation Request Acceptance... Administration Questions 8 November 2002 Answers Results Approval... Other: ML030370139, ML031910436, ML032270057, ML032691406
MONTHYEAR2003-05-27 [Table View]

ML032691406

Text

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