ML20133Q388
| ML20133Q388 | |
| Person / Time | |
|---|---|
| Site: | Salem  |
| Issue date: | 01/17/1997 |
| From: | Stolz J Office of Nuclear Reactor Regulation |
| To: | Public Service Electric & Gas Co, Philadelphia Electric Co, Delmarva Power & Light Co, Atlantic City Electric Co |
| Shared Package | |
| ML20133Q391 | List: |
| References | |
| DPR-70-A-187, DPR-75-A-170 NUDOCS 9701280088 | |
| Download: ML20133Q388 (20) | |
Text
.
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'e UNITED STATES s
j NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 2000H001 PUBLIC SERVICE ELECTRIC & GAS COMPANY PHILADELPHIA ELECTRIC COMPANY l
DELMARVA POWER AND LIGHT COMPANY ATLANTIC CITY ELECTRIC COMPANY DOCKET NO. 50-272 i
SALEM NUCLEAR GENERATING STATION. UNIT NO. 1 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No.187 License No. DPR-70 1.
The Nuclear Regulatory Comission (the Comission or the NRC) has found that:
A.
The application for amendment filed by the Public Service Electric &
Gas Company, Philadelphia Electric Company, Delmarva Power and Light Company and Atlantic City Electric Company (the licensees) dated October 1, 1996, supplemented October 31,1996, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Comission's rule and regulations set forth in 10 CFR Chapter I; B.
The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Comission; C.
There is reasonable assurance: (i) 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 Comission's regulations set forth in 10 CFR l
Chapter I; D.
The issuance of this amendment will not be inimical to the comon defense and security or to the health and safety of the public; and t
E.
The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied.
[
2.
Accordingly, the license is amended by changes to the Technical Specifica-tions as indicated in the attachment to this license amendment, and paragraph 2.C.(2) of Facility Operating License No. DPR-70 is hereby l
amended to read as follows:
9701280088 970117 i
PDR ADOCK 05000272 P
1
. l (2) Technical Snecifications and Environmental Protection Plan The lechnical Specifications contained in Appendices A and B, as revised through Amendment No.187, 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 its date of issuance, to be implemented prior to entry into Mode 3 from the current outage.
FOR THE NUCLEAR REGULATORY COMISSION L
J y. Stolz, Director /
Project Directorate I-Division of Reactor Projects - I/II Office of Nuclear Reactor Regulation i
Attachment:
Changes to the Technical Specifications Date of Issuance: January 17, 1997
ATTACHMENT TO LICENSE AMENDMENT NO.187 FACILITY OPERATING LICENSE NO. DPR-70 DOCKET NO. 50-272 Revise Appendix A as follows:
Remove Paaes Insert Paaes 3/4 3-14 3/4 3-14 3/4 3-23 3/4 3-23 3/4 3-28 3/4 3-28 3/4 3-29 3/4 3-29 3/4 3-32a 3/4 3-32a 3/4 3-34 3/4 3-34 3/4 7-10 3/4 7-10 i
l f
l I
INSTRUMENTATION 3/4.3.2 ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION LIMITING CONDITION FOR OPERATION
==================================================================
3.3.1.1 The Er.gineered Safety Feature Actuation System (ESEAS) instru-mentation channels and interlocks shown in Table 3.3-3 shall be OPERABLE with their trip setpoints set consistent with the vslues shown in the Trip Setpoint column of Table 3.3-4 and with RESPONSE TIMES as shown in Table 3.3-5.
APPLICABILITY: As shown in Table 3.3-3.
ACTION:
a.
With an ESEAS instrumentation channel trip setpoint less conserva-tive than the value shown in the Allowable Values column of Table 3.3-4, declare the channel inoperable and apply the applicable ACTION requirement of Table 3.3-3 until the channel is restored to OPERABLE status with the trip setpoint adjusted consistent with the Trip Setpoint value, b.
With an ESEAS instrumentation channel inoperable, take the ACTION shown in Table 3.3-3.
SURVEILLANCE REQUIREMENTS j
==============================================================
l 4.3.2.1.1 Each ESEAS instrumentation channel shall be demonstrated j
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 interlocks shall be demonstrated OPERABLE during the automatic actuation logic test The total interlock function shall be demonstrated OPERABLE at least once per 18 months during CHANNEL CALIBRATION testing of each channel affected by interlock operation.
4.3.2.1.3 The ENGINEERED SAFETY FEATURES RESPONSE TIME of each ESEAS function shall be demonstrated to be within the limit at least once per 18 months.
Each test shall include at least one logic train such that both logic trains are tested at least once per 36 months and one channel per function such that all channels are tested at least once per N times 18 months where N is the total number of redundant channels in a specific ESEAS function as shown in the " Total No. of Channels" Column of Table 3.3-3.
The provisions of Specification 4.0.4 are not applicable to MSIV closure time testing.
SALEM - UNIT 1 3/4 3-14 Amendment No. 107
l TABLE 3.3-4 ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION TRIP SETPOINTS FUNCTIONAL UNIT TRIP SETPOINT ALIDWABLE VALUES i
1.
SAFETY INJECTION, W INE TRIP AND t
FEEDWATER ISOLATION a.
Manual Initiation Not Applicable Not Applicable b.
Automatic Actuation Logic Not Applicable Not Applicable c.
Containment Pressure--High s4.0 psig s4.5 psig i
d.
Pressurizer Pressure--Low a1765 psig a1755 psig e.
Differential Pressure s100 psi s112 psi Between Steam Lines--High f.
Steam Flow in Two Steam Lines--
sA function defined as sA function defined as High Coincident with T,g--Low-Low follows: A Ap corresponding follows: A Ap corresponding or Steam Line Pressure--Low to 40% of full steam flow to 44% of full steam flow between 0% and 20% load between 0% and 20% load and and then a Ap increasing then a Ap increasing linearly linearly to a Ap correspond-to a Ap corresponding to ing to 110% of full steam 111.5% of full steam flow flow at full load at full load T,g a 543*F T,
a 541*F
= 600 psig steam line a 579 psig steam line l
pressure pressure i
SALEM - UNIT 1 3/4 3-23 Amendment No.187
,.. _~.
.. -. ~.- -
..... =.
I
-a TABLE 3.3-5 (Continued) i i
ENGINEERED SAFETY FEATVFES RESPONSE TIMES INITIATING SIGNAL AND FUNCTION RESPONSE TIME IN SECQ@j, l
3.
Pressurizer Pressure-Low a.
Safety Injection (ECCS) s 27.0*/12.0*
b.
. Reactor Trip (from SI) s 2.0 c.
Feedwater Isolation s 10.0 d.
Containment Isolation - Phase "A"
s 18.00 e.
Containment Ventilation Isolation Not Applicable f.
Auxiliary Feedwater Pumps s 60 g.
Service Water System s 49.0*/13.0*
4.
Differential Pressure Between Steam Lines-Hioh a.
Safety Injection (ECCS) s 12.0*/22.0*
b.
Reactor Trip (from SI) s 2.0 c.
Feedwater Isolation s 10.0 17.0*/27.0*
d.
Containment Isolation - Phase "A"
s e.
Containment Ventilation Isolation Not Applicable f.
Auxiliary Feedwater Pumps s 60 13.0*/48.0*
g.
Service Water System s
5.
Steam Flow in Two Steam Lines - Hioh coincident with T, -- Low-Low y
a.
Safety Injection (ECCS) s 15.750/25.75*
s 5.75 b.
Reactor Trip (from SI) c.
Feedwater Isolation s 15.0 d.
Containment Isolation - Phase "A"
s 20.75m/30.75*
I e.
Containment Ventilation Isolation Not Applicable
-f.
Auxiliary Feedwater Pumps s 61.75 g.
Service Wattr System s 15.75*/50.75*
h.
' Steam Line Icolation s 10.75 l
)
SALEM - UNIT 1 3/4 3-28 Amendment No.107
t l
TABLE 3.3-5 (Continued)
ENGINEERED SAFETY FEATURES RESPONSE TIMES INITIATING SIGNAL AND FUNCTION RESPONSE TIME IN SECONDS 6.
Steam Flow in Two Steam Lines-Hich Coincident with Steam Line Pressure-Low a.
Safety Injection (ECCS) s 12.0m/22.0*
b.
Reactor Trip (from SI) s 2.0 f
c.
Feedwater Isolation s 10.0 17.0m/27.0*
d.
Containment Isolation-Phase "A"
s e.
Containment Ventilation Isolation Not Applicable f.
Auxiliary Feedwater Pumps s 60 14.0*/48.0*
g.
Service Water System s
l h.
Steam Line Isolation s 8.0 7.
Containment Pressure--Hich-Hioh a.
Containment Spray s 33.0 i
b.
Containment Isolation-Phase "B"
Not Applicable 1
c.
Steam Line Isolation s 7.0 i
8.
Steam Generator Water Level--Hich Hich a.
Turbine Trip s 2.5 b.
Feedwater Isolation s 10.0 i.
9.
Steam Generator Water Level--Low-Low a.
Motor-Driven Auxiliary Feedwater Pumps (4) s 60.0 b.
' Turbine-Driven Auxiliary Feedwater Pumps (5) s 60.0 4
1 SALEM - UNIT 1 3/4 3-29 Amendment No.107
~
p 1
TABLE 4.3-2 (Continued)
ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMIDrTATION SURVEILLANCE REQUIREMENTS CHANNEL MODES IN WHICH CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST REQUIRED 4.
STEAM LINE ISOLATION i
a.
Manual N.A.
N.A.
R 1,2,3**
I b.
Automatic Actuation Logic N.A.
N.A.
. M(2) 1,2,3 c.
Containment Pressure--
S R
Q(3) 1,2,3 High-High d.
Steam Flow in Two Steam S
R Q
1,2,3 Lines--High Coincident with T,--Low-Low or Steam Line Pressure--Low 5.
TURBINE TRIP AND FEEDWATER ISOLATION a.
Steam Generator Water S
R Q
1,2,3 Level--High-High 6.
SAFEGUARDS EQUIPMENT CONTROL SYSTEM (SEC) LOGIC a.
Inputs N.A.
N.A.
M(6) 1,2,3,4 b.
Logic, Timing and Outputs
- N.A.
N.A.
M(1) 1,2,3,4 7.
UNDERVOLTAGE, VITAL BUS a.
Loss of Voltage S
R M
1,2,3 b.
Sustained Degraded Voltage S
R M
1,2,3 SALEM - UNIT 1 3/4 3-32a Amendment No.187
TABLE 4.3-2 (Continued)
TABLE NOTATION Outputs are up to, but not including, the. output relays.
The provisions of Specification 4.0.4 are not applicable.
l (1)
Each logic channel shall be tested at least once per 62 days on a STAGGERED TEST BASIS. The CHANNEL FUNCTION TEST of each logic channel shall verify that its associated diesel generator automatic load sequence timer is OPERABLE with the interval between each load block within 1 second of its design interval.
(2)
Each train or logic channel shall be tested at least every 62 days on a staggered basis.
(3)
The CHANNEL FUNCTIONAL TEST shall include exercising the transmitter by applying either a vacuum or pressure to the appropriate side of the transmitter.
(4) NOT USED (5) NOT USED (6)
Inputs from Undervoltage, Vital Bus, shall be tested monthly.
Inputs from Solid State Protection System shall be tested every 62 days on a STAGGERED TEST BASIS.
SALEM - UNIT 1 3/4 3-34 Amendment No.107
l-PLANT SYSTEMS MAIN STEAM LINE ISOLATION VALVES
+
LIMITING CONDITION FOR OPERATION 3.'7.1.5 Each main steam line isolation valve shall be OPERABLE.
APPLICABILITY: MODES 1, 2 and 3.
ACTION:
MODES 1 - With one main steam line isolation valve inoperable, POWER OPERATION may continue provided the inoperable valve is either restored to OPERABLE status or closed within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />; otherwise, be in MODE 2 within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.
MODES 2 - With one or more main steam line isolation valve (s) inoperable, and 3 subsequent operation in MODES 2 or 3 may proceed provided; a.
The isolation valve (s) is (are) maintained closed, and b.
The isolation valve (s) is (are) verified closed once per 7 days.
Otherwise, be in MODE 3, HOT STANDBY, within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />, and MODE 4, HOT SHUTDOWN, within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.
SURVEILLANCE REQUIREMENTS 4.7.1.5 Each main steam line isolation valve shall be demonstrated OPERABLE by verifying full closure within 5 seconds when tested pursuant to Specification 4.0.5.
The provisions of Specification 4.0.4 are not applicable.
1 SALEM - UNIT 1 3/4 7-10 Amendment No.187
LA It?U
,p UNITED STATES s
j NUCLEAR REGULATORY COMMISSION 4"
WASHINGTON, D.C. 20666 4001 49.....,o PUBLIC SERVICE ELECTRIC & GAS COMPANY PHILADELPHIA ELECTRIC COMPANY DELMARVA POWER AND LIGHT COMPANY ATLANTIC CITY ELECTRIC COMPANY DOCKET NO. 50-311 SALEM NUCLEAR GENERATING STATION. UNIT NO. 2 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No.170 License No. DPR-75 1.
The Nuclear Regulatory Commission (the Commission or the NRC) has found that:
A.
The application for amendment filed by the Public Service Electric &
Gas Company, Philadelphia Electric Company, Delmarva Power and Light Company and Atlantic City Electric Company (the licensees) dated October 1, 1996, supplemented October 31, 1996, 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; B.
The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; C.
There is reasonable assurance: (i) 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 set forth in 10 CFR Chapter I; D.
The issuance of this amendment will not be inimical to the common 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 Commission's regulations and all applicable requirements have been satisfied.
2.
Accordingly, the license is amended by changes to the Technical Specifica-tions as indicated in the attachment to this license amendment, and paragraph 2.C.(2) of Facility Operating License No. DPR-75 is hereby amended to read as follows:
l
\\
(2) Technical Snecifications and Environmental Protection Plan The Technical Specifications contained in Appendices A and B, as revised through Amendment No.170, 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 its date of issuance, to be implemented prior to entry into Mode 3 from the current outage.
FOR THE NUCLEAR REGULATORY COMMISSION bl J
F. Stolz, Directo P oject Directorate IL,rE Division of Reactor Projects - I/II Office of Nuclear Reactor Regulation
Attachment:
Changes to the Technical
{
Specifications l
I Date of Issuance: January 17, 1997 i
i 4
I S
6 d
T J
(
ATTACHMENT TO LICENSE AMENDMENT N0.170 E8CJLITY OPERATING LICENSE NO. DPR-75 DOCKET NO. 50-311 Revise Appendix A as follows:
Remove Paaes Insert Paaes 3/4 3-14 3/4 3-14 3/4 3-24 3/4 3-24 3/4 3-29 3/4 3-29 3/4 3-30 3/4 3-30 3/4 3-35 3/4 3-35 3/4 3-37 3/4 3-37 3/4 7-10 3/4 7-10 t.
4 4
d i
5
---+
e w
a
1 INSTRUMENTATION 3/4.3.2 ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION i
LIMITING CONDITION FOR OPERATION 3.3.2.1 The Engineered Safety Feature Actuation System (ESEAS) instrumentation channels and interlocks 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 and with RESPONSE TIMES as shown in Table 3.3-5.
APPLICABILITY: As shown in Table 3.3-3.
ACTION:
a.
With an ESFAS instrumentation channel trip setpoint less conservative than the value shown in the Allowable values column of Table 3.3-4, declare the channel inoperable and apply the applicable ACTION requirement of Table 3.3-3 until the channel is restored to OPERABLE status with the trip setpoint adjusted consistent with the Trip Setpoint value.
b.
With an ESFAS instrumentation channel inoperable, take the ACTION shown in Table 3.3-3.
SURVEILLANCE REQUIREMENTS 4.3.2.1.1 Each ESFAS instrumentation channel shall be demonstrated OPERABLE by the performance of the CHANNEL CHECK, CHANNEL CALIBRATION and CHANNEL FUNCTIONAL TEST operations for the MODES and at frequencies shown in Table 4.3-2.
4.3.2.1.2 The logic for the interlocks shall be demonstrated OPERABLE during the automatic actuation logic test. The total interlock function l
shall be demonstrated OPERABLE at least once per 18 months during CHANNEL CALIBRATION testing of each channel affected by interlock operation.
4.3.2.1.3 The ENGINEERED SAFETY FEATURES RESPONSE TIME of each ESFAS function shall be demonstrated to be within the limit at least once per 18 months. Each test shall include at least one logic train such that both logic trains are tested at least once per 36 months and one channel per function such that all channels are tested at least once per N times 18 months where N is the total number of redundant channels in a specific ESFAS function as shown in the " Total No. of Channels" Column of Table 3.3-3.
The provisions of Specification 4.0.4 are not applicable to MSIV closure time testing.
j 1
SALEM - UNIT 2 3/4 3-14 Amendment No. 170 i
--J
-n-.
. - _.. ~..
TABLE 3.3-4 l
ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION TRIP SETPOINTS j
I I
FUNCTIONAL UNIT TRIP SETPOINT ALIONABLE VALUES 1.
SAFETY INJEC"rION, TURBINE TRIP AND
[
FEEDWATER ISOLATION r
a.
Manual Initiation Not Applicable Not' Applicable b.
Automatic Actuation Logic Not Applicable Not Applicable f
?
4.0 psig s 4.5 psig c.
Containment Pressure--High s
d.
Pressurizer Pressure--Low
= 1765 psig
= 1755 psig 100 psi s'112 psi e.
Differential. Pressure Between s
Steam Lines--High f.
Steam Flow in Two Steam Lines--
s A function defined as s A function defined as High Coincident with T.,,--Low-Low follows: A Ap corresponding follows: A dp corresponding' or Steam Line Pressure--Low to 40% of full steam flow to 44% of full steam flow between 0% and 20% load between 0% and 20% load and and then a Ap increasing then a Ap increasing linearly linearly to a Ap correspond-to a jp corresponding to ing to 110% of full steam 111.5% of full ~ steam flow at flow at full load full load a 543*F T,:a 541*F T,
a 600 psig steam line a 579 psig steam line l
pressure pressure SALEM - UNIT 2 3/4 3-24 Amendment No. 170
P p
L 9
TABLE 3.3.5 (Continued)
ENGINEERED SAFETY FEATURES PESPONSE TIMES INITIATING SIGNAL AND FUNCTION RESPONSE TIME IN SECONDS 3.
Pressurizer Pressure-Low a.
Safety Injection (ECCS) s 27.0*/12.0m b.
Reactor Trip (from SI) s 2.0 c.
Feedwater Isolation s 10.0 0) d.
Containment Isolation-Phase "A" s 18.0 e.
Containment Ventilation Isolation Not Applicable f.
Auxiliary Feedwater Pumps s 60 49.0*/13.00 g.
Service Water System s
4.
Differential Pressure Between Steam Lines-Hich 12.0*/22.0*
a.
Safety Injection (ECCS) s b.
Reactor Trip (from SI) s 2.0 c.
Feedwater Isolation s 10.0 17.0*/27.0*
d.
Containment Isolation Phase "A"
s e.
Containment Ventilation Isolation Not Applicable f.
Auxiliary Feedwater Pumps s 60 13.0*/48.0*
g.
Service Water System s
5.
Steam Flow in two Steam Lines Hich-coincident with T.y --Low-Low a.
Safety Injection (ECCS) s 15.75*/25.75*
b.
Reactor Trip (from SI) s 5.75 c.
Feedwater. Isolation s 15.0 j
20.75*/30.75*
J d.
Containment Isolation-Phase "A"
s e.
Containment Ventilation Isolation Not Applicable f.
Auxiliary Feedwater Pumps s 61.75 g.
Service Water System s 15.75A/50.75*
l h.
Steam Line Isolation s 10.75 SALEM - UNIT 2 3/4 3-29 Amendment No.170
~
1 I
i TABLE 3.3-5 (Continued)
ENGINEERED SAFETY FEATURES RESPONSE TIMES INITIATING SIGNAL AND FUNCTION RESPONSE TIME IN SECONDS i
1 6.
Steam Flow in Two Steam Lines-Hich 4
Coincident with Steam Line Pressure-Low a.
Safety Injection (ECCS) s 12.0*/22.0*
j
.b.
Reactor Trip (from SI) s 2.0 I
c.
Feedwater Isolation s 10.0 s 17.0 /27.0*
2 d.
Containment Isolation-Phase "A"
e.
Containment Ventilation Isolation Not Applicable f.
Auxiliary Feedwater Pumps s 60 g.
Ssrvice Water System s 14.0m/4g,om h.
Steam Line Isolation s 8.0 l
7 Containment Pressure--Hich-Hich a.
Containment spray s 33.0 b.
Containment Isolation-Phase "B"
Not Applicable c.
Steam Line Isolation s 7.0 l
B.
Steam Generator Water Level--Hich-Hich a.
Turbine Trip s 2.5 b.
Feedwater Isolation s 10.0 9.
Steam Generator Water Level --Low-Low a.
Motor-Driven Auxiliary Feedwater s 60.0 Pumps (4 )
b.
Turbine-Driven Auxiliary Feedwater s 60.0 Pumps (5)
SALEM - UNIT 2 3/4 3-30 Amendment No.170
l TABLE 4.3-2 (Continued)
ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION SURVEILLANCE REQUIREMENTS CHANNEL MODES IN WHICH CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST REOUIRED 4.
STEAM LINE ISOLATION a.
Manual N.A.
N.A.
R 1,2,3**
l b.
Automatic Actuation Logic N.A.
N.A.
M(2) 1,2,3 1
c.
Containment Pressure--
S R
Q(3) 1,2,3 High-High d.
Steam Flow in Two Steam S
R Q
1,2,3 Lines--High Coincident with Tavg--Low-Low or Steam Line Pressure--Low 5.
TURBINE TRIP AND FEEDWATER ISOLATION a.
Steam Generator Water S
R Q
1,2,3 Level--High-High 6.
SAFEGUARDS EQUIPMENT CONTROL SYSTEM (SEC) IOGIC a.
Inputs N.A.
N.A.
M(6) 1,2,3,4 b.
Logic, Timing and Outputs
- N.A.
N.A.
M (1) 1,2,3,4 7.
UNDERVOLTAGE, VITAL BUS a.
Loss of Voltage S
R M
1,2,3 b.
Sustained Degraded Voltage S
R M
1,2,3 SALEM - UNIT 2 3/4 3-35 Amendment No.170
il :.
1 I.
TABLE 4.3-2 (Continued)
TABLE NOTATION Outputs are up to, but not including, the Output Relays.
The provisions of Specification of 4.0.4 are not applicable.
l (1)
Each logic channel shall be tested at least once per 62 days on a STAGGERED TEST BASIS.
The CHANNEL FUNCTION TEST of each logic channel shall verify that its associated diesel generator automatic load sequence timer is OPERABLE with the interval between each load block within 1 second of its design interval.
(2)
Each train or logic channel shall be tested at least every 62 days on a STAGGERED TEST BASIS.
(3) The CHANNEL FUNCTIONAL TEST shall include exercising the transmitter j
by applying either a vacuum or pressure to the appropriate side of the transmitter.
(4)
If not performed in the previous 92 days.
(5) NOT USED (6)
Inputs from undervoltage, Vital Bus, shall be tested monthly.
Inputs from Solid State Protection System, shall be tested every 62 days on a STAGGERED TEST BASIS.
I SALEM - UNIT 2 3/4 3-37 Amendment No.170
PLArt SYSTEMS MAIN STEAM LINE ISOLATION VALVES LIMITING CONDITION FOR OPERATION 3.7.1.5 Each main steam line isolation valve shall be OPERABLE.
APPLICABILITY: MODES 1, 2 and 3.
ACTION:
MODES 1 - With one mai.n steam line isolation valve inoperable, POWER OPERATION may continue provided the inoperable valve.is either restored to OPERABLE status or closed within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />; otherwise, be in MODE 2 within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.
MODES 2 - With one or more main steam line isolation valve (s) inoperable, and 3 subsequent operation in MODES 2 or 3 may proceed provided; a.
The isolation valve (s) is (are) maintained closed, and b.
The isolation valve (s) is (are) verified closed once per 7
ys.
Otherwise, be in MODE 3, HOT STANDBY, within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />, and MODE 4, HOT SHUTDOWN, within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.
SURVEILLANCE REQUIREMENTS 4.7.1.5 Each main steam line isol '_on valve shall be demonstrated OPERABLE by verifying full closure within 5 seconds when tested pursuant to Specification 4.0.5.
The provisicns of Specificaiton 4.0.4 are not applicable.
SALEM - UNIT 2 3/4 7-10 Amendment No.170 l