ML20210U817
| ML20210U817 | |
| Person / Time | |
|---|---|
| Site: | Catawba  |
| Issue date: | 08/13/1999 |
| From: | Emch R NRC (Affiliation Not Assigned) |
| To: | |
| Shared Package | |
| ML20210U821 | List: |
| References | |
| NUDOCS 9908200219 | |
| Download: ML20210U817 (36) | |
Text
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,o lt UNITED STATEE g*
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NUCLEAR REGULATORY COMMISSION
's WASHINGTON, D.C. 20555-0001 o
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DUKE ENERGY CORPORATION NORTH CAROLINA ELECTRIC MEMBERSHIP CORPORATION SALUDA RIVER ELECTRIC COOPERATIVE. INC.
1 DOCKET NO. 50-413 CATAWBA NUCLEAR STATION. UNIT 1 I
AMENDMENT TO FACILITY OPERATING LICENSE Amendment No.179 License No. NPF-35
- 1. The Nuclear Regulatory Commission (the Commission) has found that:
)
A. The application for amendment to the Catawba Nuclear Station, Unit 1 (the facility)
Facility Operating License No. NPF-35 filed by the Duke Energy Corporation, acting for itself, North Carolina Electric Membership Corporation and Saluda River Electric Cooperative, Inc. (licensees), dated March 25,1999, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's rules and regulations as set forth in 10 CFR Chapter ll 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.
9908200219 990013 PDR ADOCK 05000413 P
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'. Accordingly, the license is hereby amended by page changes to the Technical Specifications as indicated in the attachment to this license amendment, and paragraph 2.C.(2) of Facility Operating License No. NPF-35 is hereby amended to read as follows:
(2) Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 179, which are attached hereto, are hereby incorporated into this licensc. Duke Energy Corporation shall operate the facility in accordance with the Technical Specifications.
- 3. This license amendment is effective as of its date of issuance and shall be implemented within 45 days of issuance.
FOR THE NUCLEAR REGULATORY COMMISSION
/
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Richard L. Emch, Jr., Chief, Section 1 Project Directorate 11 Division of Licensing Project Management Office of Nuclear Reactor Regulation
Attachment:
Technical Specification Changes Date of Issuance:
August 13, 1999
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- 2. Accordingly, the license is hereby amended by page changes to the Technical Specifications as indicated in the attachment to this license amendment, and paragraph 2.C.(2) of Facility Operating License No. NPF-35 is hereby amended to read as follows:
(2) Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 179, which are attached hereto, are hereby incorporated into this license. Duke Energy Corporation shall operate the facility in accordance with the Technical Specifications.
- 3. This license amendment is effective as of its date of issuance and shall be implemented within 45 days of issuance.
FOR THE NUCLEAR REGULATORY COMMISSION
/
Richard L. Emch, Jr., Chief, Section 1 Project Directorate 11 Division of Licensing Project Management Office of Nuclear Reactor Regulation
Attachment:
Technical Specification Changes j
Date of issuance:
August 13, 1999 i
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UNITED S'TATES g,k [/
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,j NUCLEAR REGULATORY COMMISSION 2
g WASHINGTON, D.c. 20555-0001 s,..u DUKE ENERGY CORPORATION NORTH CAROLINA MUNICIPAL POWER AGENCY NO.1 PIEDMONT MUNICIPAL POWER AGENCY DOCKET NO. 50-414 CATAWBA NUCLEAR STATION. UNIT 2 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No. 171 License No. NPF-52
- 1. The Nuclear Regulatory Commission (the Commission) has found that:
A.
The application for amendment to the Catawba Nuclear Station, Unit 2 (the facility)
Facility Operating License No. NPF-52 filed by the Duke Energy Corporation, acting for itself, North Carolina Municipal Power Agency No.1 and Piedmont Municipal Power i
Agency (licensees), dated March 25,1999, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's rules and regulations as 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 amendrnent is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied.
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- 2. ' Accordingly, the license is hereby amended by page changes to the Technical Specifications as indicated in the attachment to this license amendment, and Paragraph 2.C.(2) of Facility Operating License No. NPF-52 is hereby amended to read as follows:
(2) Technical Soecifications The Technical Specifications contained in Appendix A, as revised through o
Amendment No.171, which are attached hereto, are hereby incorporated into this license. Duke Energy Corporation shall operate the facility in accordance with the Technical Specifications.
- 3. This license amendment is effective as of its date of issuance and shall be implemented within 45 days of issuance.
FOR THE NUCLEAR REGULATORY COMMISSION Richard L. Emch, Jr., Chief, Section 1 Project Directorate 11 Division of Licensing Project Management Office of Nuclear Reactor Regulation i
Attachment:
Technical Specification Changes Date of issuance:
August 13, 1999 l
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ATTACHMENT TO LICENSE AMENDMENT NO.
179 FACILITY OPERATING LICENSE NO. NPF-35 DOCKET NO. 50-413 AND LICENSE AMENDMENT NO. 1 71 FACILITY OPERATING LICENSE NO. NPF-52 DOCKET NO. 50-414 O
Replace the following pages of Appendix A Technical Specifications with the attached revised pages. The revised pages are identified by amendment number and contain marginal lines indicating the areas of change.
Remove Insert 1.1-4 1.1-4 i
1.1-5 1.1-5 1.1-6 1.1-6 1.1 -7 1.1-7 3.3.1-14 3.3.1-14 3.3.1-15 3.3.1-15 3.3.1-16.
3.3.1-16 3.3.1-17 3.3.1-17 3.3.1-18 3.3.1-18 3.3.1-19 3.3.1-19 3.3.2 11 3.3.2-11 3.3.2-12 3.3.2-12 3.3.2-13 3.3.2-13 3.3 2-14 3.3.2-14 3.3.2-15 3.3.2-15 3.3.5-2 3.3.5-2 3.3.6-3 3.3.6-3 3.4.12-1 3.4.12-1 Replace the following pages of the Technical Specifications Bases document with the attached revised pages. The revised pages are identified by amendment number and contain marginal lines indicating the areas of change.
Remove Insert B3.3.1 B3.3.1 -1 L
B3.3.1-2 B3.3.1 -2 B3.3.1 -4 B3.3.1 -4 e
B3.3.1-30 B3.3.1-30
8 6 Remove Insert j.,
B3.3.1-31 B3.3.1-31 B3.3.2-2 B3.3.2-2 B3.3.2-3 B3.3.2-3 B3.3.2-31 B3.3.2-31 B3.3.2-32 B3.3.2-32 B3.3.5-2 B3.3.5-2 B3.3.5-3 B3.3.5-3 B3.3.5-4 B3.3.5-4 1
i
Definitions 1.1 1.1 Definitions (continued)
MASTER RELAY TEST A MASTER RELAY TEST shall consist of energizing each master relay and verifying the OPERABILITY of each relay.
The MASTER RELAY TEST shall include a continuity check of each associated slave relay.
MODE A MODE shall correspond to any one inclusive combination of core reactivity condition, power level, average reactor coolant temperature, and reactor vessel head closure bolt tensioning specified in Table 1.1-1 with fuelin the reactor vessel.
NOMINAL TRIP SETPOINT The NOMINAL TRIP SETPOINT shall be the design value of a setpoint. The trip setpoint implemented in plant hardware may be less or more conservative than the NOMINAL TRIP SETPOINT by a calibration tolerance. If plant conditions warrant, the trip setpoint implemented in plant hardware may be set outside the NOMINAL TRIP SETPOINT calibration tolerance band as long as the trip setpoint is conservative with respect to the NOMINAL TRIP SETPOINT.
OPERABLE-OPERABILITY A system, subsystem, train, component, or device shall be OPERABLE or have OPERABILITY when it is capable of performing its specified safety function (s) and when all necessary attendant instrumentation, controls, normal or emergency electrical power, cooling and seal water, lubrication, and other auxiliary equipment that are required for the system, subsystem, train, component, or device to perform its specified safety function (s) are also capable of performing their related support function (s).
PHYSICS TESTS PHYSICS TESTS shall be those tests performed to measure the fundamental nuclear characteristics of the reactor core and related instrumentation. These tests are:
a.
Described in Chapter 14 of the UFSAR; i
b.
Authorized under the provisions of 10 CFR 50.59; or c.
Otherwise approved by the Nuclear Regulatory Commission.
QUADRANT POWER TILT OPTR shall be the ratio of the maximum upper excore i
detector calibrated cutf ut to the average of the upper excore RATIO (OPTR) detector calibrated outputs, or the ratio of the maximum lower excore detector calibrated output to the average of the lower excore detector calibrated outputs, whichever is greater.
(continued)
Catawba Units 1 and 2 1.1-4 Amendment Nos.179 (Unit 1)!
171 (Unit 2}l
Definitions 1.1 i
i 1.1 Definitions (continued)
RATED THERMAL POWER RTP shall be a total reactor core heat transfer rate to the (RTP) reactor coolant of 3411 MWt.
REACTOR TRIP The RTS RESPONSE TIME shall be that time interval from SYSTEM (RTS) RESPONSE when the monitored parameter exceeds its RTS trip setpoint TIME at the channel sensor until loss of stationary gripper coil voltage. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.
SDM shall be the instantaneous amount of reactivity by which l
the reactor is suberitical or would be suberitical from its present condition assuming:
a.
All rod cluster control assemblies (RCCAs) are fully inserted except for the single RCCA of highest reactivity worth, which is assumed to be fully withdrawn. With any RCCA not capable of being fully inserted, the reactivity worth of the RCCA must be accounted for in the determination of SDM; and I
b.
In MODES 1 and 2, the fuel and moderator temperatures are changed to the nominal zero power design level.
SLAVE RELAY TEST-A SLAVE RELAY TEST shall consist of energizing each slave relay and verifying the OPERABILITY of each slave relay. The SLAVE RELAY TEST shall include, as a minimum, a continuity check of associated testable actuation devices.
STAGGERED TEST BASIS A STAGGERED TEST BASIS shall consist of the testing of one of the systems, subsystems, channels, or other designated components during the interval specified by the Surveillance Frequency, so that all systems, subsystems, channels, or other designated components are tested during n Surveillance Frequency intervals, where n is the total number of systems, subsystems, channels, or other designatM components in the associated function.
THERMAL POWER THERMAL POWER shall be the total reactor core heat transfer rate to the reactor coolant.
Catawba Units 1 and 2 1.1 5 Amendment Nos.179 (Unit 1) >
171 (Unit 2)
Definitions 1.1 1.1 Definitions (continued)
TRIP ACTUATING DEVICE A TADOT shall consist of operating the trip actuating device OPERATIONAL TEST and verifying the OPERABILITY of required alarm, interlock, (TADOT) and trip functions. The TADOT shallinclude adjustment, as necessary, of the trip actuating device so that it actuates at the required setpoint within the required accuracy.
i Catawba Units 1 and 2 1.1-6 Amendment Nos.179 (Unit 1) 171 (Unit 2)
I Definitions 1.1 Table 1.1-1 (page 1 of 1)
MODES AVERAGE REACTIVITY
% RATED REACTOR COOLANT CONDITION THERMAL TEMPERATURE MODE TITLE (kg)
POWER (a)
(*F) 1 Power Operation 2 99
>5 NA 0
2 Startup 0
2 99 5 5 NA 3
Hot Standby
< 0.99 NA
> 350 4
Hot Shutdown (b)
< 0.99 NA 350 > T,y > 200 5
Cold Shutdown (b)
< 0.99 NA 5 200 6
Refueling (c)
NA NA NA (a)
Excluding decay heat.
(b)
All reactor vessel head closure bolts fully tensioned.
(c)
One or more reactor vessel head closure bolts less than fully tensioned.
Catawba Units 1 and 2 1.1-7 Amendment Nos.179 (Unit 1) 171 (Unit 2)
RTS Instrumentation 3.3.1 Table 3.31 1 (page 1 of 7)
Reactor Trip System instrumentation APPLICABLE MODES OR OTHER NOMINAL l
SPECIFIED REQUIRED SUPVEILLANCE ALLOWABLE TRIP FUNCTION
. CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE SETPOINT l
1.
Manual Reactor Trip 1,2 2
B SR 3.3.1.14 NA NA 3(a)4(a)$(a) 2 C
SR 3.3.1.14 NA NA 2.
Power Range Neutron Flux a.
High 1.2 4
D SR 3.3.1.1 s 110.9 %
109% RTP l
SR 3.3.1.2 RTP SR 3.3.1.7 SR 3.3.1.11 SR 3.3.1.16 b.
Low 1(b) 2 4
E SR 3.3.1.1 s 27.1% RTP 25% RTP l
SR 3.3.1.8 SR 3.3.1.11 SR 3.3.1.16 3.
Power Range Neutron Flux High Positive Rate 1,2 4
D GR 3.3.1.7 s 6.3% RTP 5% RTP l
SR 3.3.1.11 with time with time constant constant 2 2 sec 2 2 sec 4 Intermediate Range g(b) 2(c) 2 F,G SR 3.3.1.1 s 31% RTP 25% RTP l
Neutron Flux SR 3.3.1.8 SR 3.3.1.11 2(d) 2 H
SR 3.3.1.1 s 31% RTP 25% RTP l
SR 3.3.1.8 SR 3.3.1.11 5.
Source Range 2(d) 2 1.J SR 3.3.1.1 s 1.4 E5 cps 1.0 E5 cps l
Neutron Rux SR 3.3.1.8 SR 3.3.1.11 3(a)4(a)5(a) 2 J,K SR 3.3.1.1 s 1.4 E5 1.0 E5 cps l
SR 3.3.1.7 cps SR 3.3.1.11
- 6. Overtemperature AT 1.2 4
E SR 3.3.1.1 Refer to Refer to SR 3.3.1.3 Note 1 (Page Note 1 SR 3.3.1.6 3.3.1 18)
(Page SR 3.3.1.7 3.3.1 18)
SR 3.3.1.10 SR 3.3.1.16 SR 3.3.1.17 (continued)
(1) With Reactor Tnp Breakers (RTBs) closed and Rod Control System capable of rod withdrawal.
(b) Below the P 10 (Power Range Neutron Flux) interlocks.
(c) Above the P4 (intermediate Range Neutron Flux) interlocks.
(d) Below the P-6 (Intermediate Range Neutron Flux) interlocks.
Catawba Units 1 and 2 3.3.1 14 Amendment NoS.179 (Unit 1) 171 (Unit 2) l
RTS instrumentation
'.3.1 o
Table 3.3.1 1 (page 2 of 7)
Reactor Trip System instrurnentation APPLICABLE MODES OR OTHER NOMINAL l
SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE TRIP FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE SETPOINT 7.
Overpower AT 1,2 4
E SR 3 3.1.1 Refer to Refer to SR 3.3.1.3 Note 2 (Page Note 2 SR 3 3.1.6 3.3.1 19)
(Page SR 3.3.1.7 3.3.1-19)
SR 3.3.1.10 SR 3.3.1.16 SR 3.3.1.17 8.
Pressurizer Pressure a.
Low 1(e) 4 L
SR 3.3.1.1 21938(0 psig 1945(I) l SR 3.3.1.7 psig SR 3.3.1.10 SR 3.3.1.16 b.
High 1.2 4
E SR 3.3.1.1 5 2399 psig 2385 psig l
SR 3.3.1.7 SR 3.3.1.10 SR 3.3.1.16 9.
Pressurizer Water g(e) 3 L
SR 3.3.1.1 5 93.8 %
92%
l Level-High SR 3.3.1.7 SR 3.3.1.10
- 10. Reactor Coolant Flow - Low a.
Single Loop g(g) 3 per loop M
SR 3.3.1.1 2 89.7 %
91 %
l 1
{
b.
Two Loops 3(h) 3 per loop L
SR 3.3.1.1 2 89.7 %
91 %
l SR 3.3.1.7 SR 3.3.1.10 SR 3.3.1.16 (continued)
(:) Above the P-7 (Low Power Reactor Trips Block) interlock.
(f) Time constants utilized in the lead-lag controller for Pressurtzer Pressure - Low are 2 seconds for lead and 1 second for lag.
(g) Above the P-8 (Power Range Neutron Flux) intertock.
(h) Above the P-7 (Low Power Reactor Trips Block) interlock and below the P-8 (Power Range Neutron Flux) intertock.
l Catawba Units 1 and 2 3.3.1-15 Amendment NoS.179 (Unit 1) 171 (Unit 2)
RTS Instrumentation 3.3.1 -
- Table 3.3.1 1 (page 3 of 7)
- Reactor Tnp System instrumentation APPLICABLE '
MODES OR OTHER NOMINAL l
SPECIFIED REOUIRED.
SURVEILLANCE ALLOWABLE TRIP FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE SETPOINT
- 11. Undervoltage RCPs 3(e) 1 per bus L
SR 3.3.1.9 2 5016 V 5082 V l
- 12. Underfrequency 3(e) 1 per bus L
SR 3.3.1.9 2 55.9 H2 56.4 H2 l
- 13. Steam Generator 1.2 4 per SG E
SR 3.3.1.1 2 9% (Unit 1) 10.7%
(SG) Water Level.
SR 3.3.1.7 2 35.1 %
(Unit 1)
Low Low SR 3.3.1.10 (Unit 2) of 36.8 %
SR 3.3.1.16 narrow range (Unit 2) of span nanow range span
- 14. TurbineTrip a.
Stop Valve EH 10) 4 N
SR 3.3.1.10 2 500 psig 550 psig l
Pressure Low -
SR 3.3.1.15 b.
Turbine Stop '
10) 4 O
SR 3.3.1.10 21% open NA l
Valve Closure SR 3.3.1.15
- 15. SafetyIntecten(SI) 1.2 2 rains P
SR 3.3.1.5 NA NA Input trorn SR 3.3.1.14 Engineered Safety Feature Actuaton System (ESFAS)
(continued)
(e) Above the P-7 (Low Power Reactor Trips Block) interlock.
(i) Not used.
- 0) Above the P-9 (Power Range Neutron Flux) interlock.
Catawba Units 1 and 2 3.3.1-16 Amendment NoS. 179 (Unit 1) 171 (Unit 2)
RTS Instrumentation 3.3.1
.TatWe 3.3.1 1 (page 4 of 7) i Reactor Tnp System instrumentation APPLICABLE -
4 MODES OR OTHER NOMINAL l
SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE TRIP FUNCTION CONDITIONS CHANNELS CONDmONS REQUIREMENTS VALUE SETPOINT
- 16. Reactor Trip System Interlocks a.
Intermediate 2(d) 2.
R SR 3.3.1.11 2 6E 11 amp 1 E-10 amp l
Range Neutron -
Low Power 1
1 per train S
SR 3.3.1.5 NA NA Reactor Trips Block, P-7 g
. c.
Power Range 1
4 S
SR 3.3.1.11 5 50.2% RTP 48% RTP l
Neutron Flux, SR 3.3.1.13 P-8 d.
Power Range 1
4 S
SR 3.3.1.11 s 70% RTP 69% RTP l
Neutron Flux.
Power Range 12 4
R SR 3.3.1.11 2 7.8% RTP 10% RTP l
Neutron Flux, SR 3.3.1.13 P 10 and 5122%
RTP f.
Turbine 1
2 S
s 12.2% RTP Impulse SR 3.3.1.13 IUDA' Pressure, P 13 turbine impulse impulse pressure pressure equivalent equivalent 17, ReactorTrip 1,2 2 trains Q,U SR 3.3.1.4 NA NA Breakers (k) 3(a)4(a),5(a) 2 trains C
SR 3.3.1.4 NA NA
- 18. Reactor Tnp Breaker 1,2 1 each per T
SR 3.3.1 A NA NA Undervoltage and RTB Shunt Trip Mechanisms 3(a),4(a)5(a) 1 each per C
SR 3.3.1.4 NA NA RTB 19, Automatic Trip Logic 1,2 2 trains P,U SR 3.3.1.5 NA NA 3(a)4(a)$(a) 2 trains C
SR 3.3.1.5 NA NA (continued) 1
(:) With RTBs closed and Rod Control System capable of rod withdsawal.
(d) Below the P-6 (intermediate Range Neutron Flux) interlocks.
(k) includmg any reactor trip bypass breakers that are racked in and closed for bypassing an RTB.
. Catawba Units 1 and 2 3.3.1-17 Amendment NoS. 179 (Unit 1) 171 (Unit 2) i t
RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 5 of 7)
Reactor Trip System Instrumentation Note 1: Overtemperature AT The Overtemperature AT Function Allowable Value shall not exceed the following NOMINAL TRIP SETPOINT by more than 4.5% of RTP.
s T ' * *' ') '
I K, - K, ((' * ' T
- T'
+ K, (P - P') - f, (bi)
SATo (1 + r, s, 1 + r3 s,
1 + r, s)
(1 + r, s)
Where: AT is the measured RCS AT by loop narrow range RTDs, "F.
ATo is the indicated AT at RTP, 'F.
s is the Laplace transform operator, se6'.
T,is the measured RCS average temperature, 'F.
T is the nominal T., at RTP (allowed by Safety Analysis), s 585.1*F (Unit 1) s 590.8*F (Unit 2).
P,is the measured pressurizer pressure, psig P is the nominal RCS operating pressure, = 2235 psig Overtemperature AT reactor NOMINAL TRIP SETPOINT, as presented in l
Ki
=
the COLR, K
Overtemperature AT reactor trip heatup setpoint penalty coefficient, as 2
=
presented in the COLR, i
Ka Overtemperature AT reactor trip depressurization setpoint penalty
=
coefficient, as presented in the COLR, Time constants utilized in the lead-lag compensator for AT, as presented in ti, t,
=
the COLR, Time constant utilized in the lag compensator for AT, as presented in the T3
=
- COLR, Time constants utilized in the lead-lag compensator for T.y, as presented t., t.
=
in the COLR, Time constant utilized in the measured T y ag compensator, as presented l
t,
=
in the COLR, and f (AI) = a function of the indicated difference between top and bottom detectors of i
the power-range r'eutron ion chambers; with gains to be selected based on measured instrument response during plant startup tests such that:
(i) for q - qn between the " positive" and " negative" fi(AI) breakpoints as presented in the COLR; f (AI) = 0, where qi and go are percent i
RATED THERMAL POWER in the top and bottom halves of the core respectively, and qi + go is total THERMAL POWER in percent of RATED THERMAL POWER; (ii) for each percent Al that the magnitude of gi-go is more negative than the f (AI)
- negative" breakpoint presented in the COLR, the AT i
Trip Setpoint shall be automatically reduced by the fi(AI) " negative" 1
slope presented in the COLR; and (continued)
Catawba Units 1 and 2 3.3.1-18 Amendment Nos. 179 (Unit 1.'
171 (Unit 2:'
L
RTS Instrumentation 3.3.1 Table 3.3.1 1 (page 6 of 7)
Reactor Trip System Instrumentation (iii) for each percent Al that the magnitude of qi-qo is more positive than the fi(AI) " positive" breakpoint presented in the COLR, the AT Trip Setpoint shall be automatically reouced by the f (AI) " positive" i
slope presented in the COLR.
Note 2: Overpower AT The Overpower AT Function Allowable Value shall not exceed the following NOMINAL TRIP SETPOINT by more than 3% (Unit 1) 3.3% (Unit 2) of RTP.
AT ( * *' #5 D#
SAT K, - K,1 + 7 T - K.
T
- T' - f, ( AI)j>
o (1+f,s) 1+T 5 S
1+r.s, 1 + r. s 3
7 Where: AT is the measured RCS AT by loop narrow range RTDs, *F.
ATo is the indicated AT at RTP, *F.
s is the Laplace transform operator, sec.
T,is the measured RCS average temperature, 'F.
T is the nominal T.y at RTP (calibration temperature for AT instrumentation),
s 585.1*F (Unit 1) S 590.8'F (Unit 2).
Overpower AT reactor NOMINAL TRIP SETPOINT as presented in the l
K4
=
- COLR, Ks 0.02/*F for increasing average temperature and 0 for decreasing average
=
temperature, Ke Overpower AT reactor, trip heatup setpoint penalty coefficient as presented
=
in the COLR for T > T and Ke = 0 for T s T,
Time constants utilized in the lead-lag compensator for AT, as presented in ti, T,
=
the COLR, l
Time constant utilized in the lag compensator for AT, as presented in the T3
=
- COLR, Time constant utilized in the measured T., lag compensator, as presented T.
=
in the COLR, Time constant utilized in the rate-lag controller for T.y, as prosented in the T,
=
COLR, and f (AI) = a function of the indicated difference between top and bottom detectors of 2
the power-range neutron ion chambers; with gains to be selected based on measured instrument response during plant startup tests such that:
1 (i) for gi - go between the " positive" and " negative" f (Al) breakpoints as 2
presented in the COLR; f (AI) = 0, where qi and go are percent 2
RATED THERMAL POWER in the top and bottom halves of the core respectively, and qi + go is total THERMAL POWER in percent of RATED THERMAL POWER; (continued)
Catawba Units 1 and 2 3.3.1-19 Amendment Nos.179 (Unit 1) 171 (Unit 2)
ESFAS instrumentation 3.3.2 Table 3.3.21 (page 1 of 5) 1 EnD neered Safety Feature Actuation System instrumentation i
APPLICABLE MODES OR OTHER NOMINAL l
SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE TRIP FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE SETPOINT 1.
Safety injection a.
Manualinitiation 1,2,3.4 2
B SR 3.3.2.8 NA NA b.
Automatic 1,2,3.4 2 trains C
SR 3.3.2.2 NA NA Actuation Logic SR 3.3.2.4 and Actuation SR 3.3.2.6 Relays c.
Containment 1,2,3 3
D SR 3.3.2.1 s 1.4 psig 1.2 psig l
Pressure - High SR 3.3.2.5 SR 3.3.2.9 SR 3.3.2.10 d.
Pressurizer 1,2,3(a) 4 D
SR 3.3.2.1 21839 psig 1845 psig l
Pressure - Low SR 3.3.2.5 SR 3.3.2.9 SR 3.3 2.10 2.
Manualinitiation 1,2,3,4 1 per train, O
SR 3.3.2.8 NA NA 2 trains b.
Automatic 1,2,3,4 2 trains C
SR 3.3.2.2 NA NA Actuation Logic SR 3.3.2.4 and Actuation SR 3.3.2.6 Relays c.
Containment 1,2,3 4
E SR 3.3.2.1 s 3.2 psig 3.0 psig l
Pressure -
SR 3.3.2.5 High High SR 3.32.9 SR 3.3.2.10 3.
Containment isolation a.
Phase A isolation (1) Manual 1,2,3,4 2
B SR 3.3.2.8 NA NA Initiation (2) Automatic 1,2,3,4 2 trains C
SR 3.3.22 NA NA Actuation SR 3.3.2.4 Logic and SR 3.3.2.6 Actuation Relays (3) Safety Refer to Function 1 (Safety injection) for all initiation functions and requirements.
Injection (continued)
(a) Above the P 11 (Pressurizer Pressure) interlock.
Catawba Units 1 and 2 3.3.2-11 Amendment NoS,179 (Unit 1) 171 (Unit 2)
ESFAS instrumentation 3.3.2 Table 3.3.2-1 (page 2 of 5)
Engineered Safety Feature Actuation System instrumentation APPLICABLE MODES OR OTHER NOMINAL l
SPECIFIED REQUIRED SURVEILLANCE ALLOWALLE TRIP FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE SETPOINT 3.
Containment isolation (continued) b.
Ptmse B tsolation (1) Manual Initiation 1,2,3,4 1 por train, B
SR 3.3.2.8 NA NA 2 trains (2) Automatic 1,2,3,4 2 trains C
SR 3.3.2.2 NA NA Actuation SR 3.3.2.4 Logic and SR 3.32.6 Actuation Relays (3) Containment 1,2,3 4
E SR 3 3.2.1 5 3.2 psig 3.0 psig l
Pressure -
SR 3.3.2.5 High High SR 3.3.2.9 SR 3.3.2.10 4.
Steam Line isolation a.
Manual initiation (1) System 1,2(b) 3(b) 2 trains F
SR 3.3.2.8 NA NA (2) Individual 1,2(b) 3(b) 1 per hne G
SR 3.3.2.8 NA NA b.
Automatic 1,2(b) 3(b) 2 trains H
SR 3.3.2.2 NA NA Actuation Logic SR 3 3.2.4 and Actuation SR 3.3.2.6 Relays 4
E SR 3.3.2.1 53.2 3.0 psig l
c.
Containment 1*2(b) 3(b)
Pressure High SR 3.32.5 psig High SR 3.3.2.9 SR 3.3.2.10 d.
Steam Line Pressure (1) Low 1,2(D)A(a)(b) 3 per steam D
SR 3.3.2.1 2 744 psig 775 psig l
line SR 3.3.2.S SR 3.3.2.9 SR 3.3.2.10 (continued)
(a) Above the P 11 (Pressuriter Pressure) interlock.
l (b)Except when all MSIVs are closed and de-activated.
Catawba Units 1 and 2 3.3.2-12 Amendment NoS.179 (Unit 1) 171 (Unit 2)
I ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 3 of 5)
Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER NOMINAL l
SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE TRIP FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE SETPOINT
- 4. Steam Line isolation (continued)
(2) Negative 3(b)(c) 3 per steam D
SR 3.3.2.1 s 122.8(d) ps 100(d) psi l
Rate - High line SR 3.3.2.5 SR 3 3.2.9 SR 3.3.2.10 5.
Turbine Trip and Feedwater isolation a.
Automatic 1.2(*)
2 trains i
SR 3.3.2.2 NA NA Actuation Logic SR 3.3.2.4 and Actuation SR 3.3.2.6 Relays b.
SG Water Level jy(e) 4 per SG J
SR 3.3.2.1 s 85.6 %
83.9 %
l High High SR 3.3.2.2 (Unit 1)
(Unit 1)
(P 14)
SR 3.3.2.4 5,78.9 %
77.1*A l
SR 3.3.2.5 (Unit 2)
(Unit 2)
SR 3.3.2.6 SR 3.3.2.9 SR 3.3.2.10 c.
Safety injection Refer to Function 1 (Safety injection) for all initiation functions and requirements.
d.
T.g-Low 1,2(8) 4 J
SR 3.3.2.1 2 561*F 564*F l
SR 3.3.2.5 SR 3.32.9 coincident with Refer to Function 8.a (Reactor Trip, P-4) for all initiation functions and Reactor Trip, P-4 requirements.
e.
Doghouse Water 3y(e) 2 per L
SR 3.3.2.8 512 inches 11 inches l
Level High High doghouse above 577 ft above 577 floor level ft floor level f.
Trip of all main jy(a) 3 per MFW K
SR 3.3.2.8 NA NA feedwater pump pumps (continued)
(1) Above the P-11 (Pressurizer Pressure)interiock.
(b) Except when all MSlVs are closed and de-activated.
(c) Trip function automatically blocked above P 11 (Pressurizer Pressure) interlock and may be blocked below P 11 when Steam Line Isolation Steam Line Pressure - Low is not blocked.
(d) Time constant utilized in the rateaag controller is 2 50 seconds.
(I) Except when all MFIVs, MFCVs, and associated bypass valves are closed and de-activated or isolated by a closed manual valve.
Catawba Units 1 and 2 3.3.2-13 Amendment NoS.179 (Unit 1) 171 (Unit 2)
ESFAS Instrumentation 3.3.2 Table 3.3.21 (page 4 of 5)
Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER NOMINAL l
SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE TRIP FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE SETPOINT 6.
Automatic 1,2,3 2 trains H
SR 3.3.2.2 NA NA Actuation Logic SR 3.32.4 and Actuation SR 3.3.2.0 Relays b.
SG Water Level 1,2,3 4 per SG D
SR 3.3.2.1 29%
10.7%
l Low Low SR 3.3.2.5 (Unit 1)
(Unit 1)
SR 3.32.9 2 35.1%
36.8 %
l SR 3.32.10 (Unit 2)
(Unit 2) c.
Safety injection Refer to Function 1 (Safety injection) for all Initiation functions and requirements.
d.
Loss of Offsite 1,2,3 3 per bus D
SR 3.32.3 2 3242 V 3500 V l
Power SR 3.3.2.9 SR 3.32.10 e.
Trip of all Main yy(a) 3 per pump K
SR 3.32.8 NA NA Feedwater SR 3.3.2.10 Pumps f.
Auxikary 1,2,3 3 per train M
SR 3.3.2.8 A) 2 9.5 psig A) 10.5 l
Feedwater Pump SR 3.3.2.10 Train A and psig Train B Suction Transfer on B) 2 S.2 psig D) 6.2 psig l
(Unit 1)
(Unit 1)
Suction Pressure Low 2 S.0 psig 6.0 psig l
(Unit 2)
(Unit 2)
- 7. Automatic Switchover to Containment Sump i
a.
Automatic 1,2,3,4 2 trains C
SR 3.3.22 NA NA i
Actuation Logic SR 3.3.2.4 and Actuation SR 3.3.2.6 Relays b.
Refueling Water 1,2,3,4 4
N SR 3.3.2.1 2 162.4 177.15 l
Storage Tank SR 3.3.2.7 inches inches (RWST) Level-SR 3.3.2.9 Low SR 3.32.10 Coincident with Refer to Function 1 (Safety injection) for all initiation functions and requirements.
Safetyinjection (continued)
(a) Above the P 11 (Pressurizer Pressure) interlock.
Catawba Units 1 and 2 3.3.2-14 Amendment NoS. 179 (Unit 1) 171 (Unit 2)
ESFAS Instrumentation 3.3.2 Table 3.3.21 (page 5 of 5)
Engineered Safety Feature Actuation Systern Instrumentation APPLICABLE MODES OR OTHER NOMINAL l
SPECIFIED REQUIRED SURVElLLANCE ALLOWABLE TRIP FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE SETPOINT 8.
ESFAS Interlocks a.
Reactor Trip, P-4 1,2,3 1 per train, F
SR 3.3 2.8 NA NA 2 trains b.
Pressurizer 1.2.3 3
O SR 3.3.2.5 21944 and 1955 psig Pressure, P-11 SR 3.3.2.9 s 1966 psig c.
T.,
Low Low, 1,2,3 1 per loop O
SR 3.3.2.5 2 550"F 553*F l
P-12 SR 3.3.2.9
- 9. Containmont Pressure Control System a.
Start Permissive 1,2,3,4 4 per train P
SR 3.3.2.1 5 0.45 psid 0.4 psid l
SR 3.3.2.9 b.
Termination 1,2,3,4 4 per train P
SR 3.3.2.1 2 0.25 psid 0.3 psid l
SR 3.3.2.7 SR 3.3.2.9
- 10. Nuclear Service 1,2,3,4 3 per pit Q,R SR 3.3.2.1 2 El. 555 4 ft El. 557.5 ft l
Water Suction SR 3.3.2.9 1ransfer Low Pit SR 3.3.2.11 Level l
i Catawba Units 1 and 2 3.3.2-15 Amendment NoS.179 (Unit 1) 171 (Unit 2)
e LOP DG Start instrumentation 3.3.5 l
SURVEILLANCE REQUIREMENTS j.
SURVEILLANCE FREQUENCY SR 3.3.5.1 NOTE---
Testing shall consist of voltage sensor relay testing excluding actuation of load shedding diesel start, and time delay times.
Perform TADOT.
31 days SR 3.3.5.2 Perform CHANNEL CALIBRATION with NOMINAL TRIP 18 months SETPOINT and Allowable Value as follows:
)
a.
Loss of voltage Allowable Value 2 3242 V.
Loss of voltage NOMINAL TRIP SETPOINT =
3500 V.
b.
Degraded voltage Allowable Value 2 3738 V.
Degraded voltage NOMINAL TRIP SETPOINT =
3766 V.
1 Catawba Units 1 and 2 3.3.5-2 Amendment Nos.179 (Unit 1) 171 (Unit 2)
Containment Purge and Exhaust isolation Instrumentation 3.3.6 Table 3.3.6-1 (page 1 of 1)
Containment Purge and Exhaust isolation Instrumentation FUNCTION REQUIRED SURVEILLANCE NOMINAL CHANNELS REQUIREMENTS TRIP SETPOINT 1.
Manual Initiation 2
SR 3.3.6.4 NA 2.
Automatic Actuation Logic and 2 trains SR 3.3.6.1 NA Actuation Relays SR 3.3.6.2 SR 3.3.6.3 3.
Safety injection Refer to LCO 3.3.2, *ESFAS Instrumentation,' Table 3.3.2-1, Function 1, for all initiation fungtions and requirements, t
Catawba Units 1 and 2 3.3.6-3 Amendment Nos. 179 (Unit 1) 171 (Unit 2)
LTOP System 3.4.12 13.4 REACTOR COOLANT SYSTEM (RCS) 3.4.12 Low Temperature Overpressure Protection (LTOP) System LCO 3.4.12' An LTOP_ System shall be OPERABLE with a maximum of one charging pump or one safety injection pump capable of injecting into the RCS, the accumulators isolated, reactor coolant pump operation limited as specified in Table 3.4.12-1 and either a or b below:
a.-
.Two power operated relief valves (PORVs) with nominallift setting = l 400 psig (as left calibrated), allowable value s 425 psig (as found),
with RCS cold leg temperature 2 65'F; or b.
The RCS depressurized and an RCS vent of 2 5 square inches.
4 APPLICABILITY:
MODE 4 when any RCS cold leg temperature is s 285'F, MODE 5, MODE 6 when the reactor vessel head is on.
-NOTE-----
Accumulator isolation is only required when accumulator pressure is
. greater than or equal to the maximum RCS pressure for the existing RCS cold leg temperature allowed by the P/T limit curves provided in Specification 3.4.3.
Catawba Units 1 and 2 3.4.12-1 Amendment Nos.179 (Unit 1) 171 (Unit 2)
s RTS Instrumentation B 3.3.1 B 3.3 INSTRUMENTATION B 3.3.1 Reactor Trip System (RTS) Instrumentation BASES BACKGROUND The RTS initiates a unit shutdown, based on the values of selected unit parameters, to protect against violating the core fuel design limits and Reactor Coolant System (RCS) pressure boundary during anticipated operational occurrences (AOOs) and to assist the Engineered Safety i
Features (ESF) Systems in mitigating accidents.
The protection and monitoring systems have been designed to assure safe operation of the reactor. This is achieved by specifying limiting safety system settings (LSSS) in terms of parameters directly monitored j
by the RTS, as well as specifying LCOs on other reactor system
]
parameters and equipment performance.
The LSSS, defined in this specification as the Allowable Value,in l
conjunction with the LCOs, establish the threshold for protective system action to prevent exceeding acceptable limits during Design Basis Accidents (DBAs).
During AOOs, which are those events expected to occur one or more times during the unit life, the acceptable limits are:
1.
The Departure from Nucleate Boiling Ratio (DNBR) shall be maintained above the Safety Limit (SL) value to prevent departure from nucleate boiling (DNB);
2.
Fuel centerline melt shall not occur; and 3.
The RCS pressure SL of 2735 psig shall not be exceeded.
Operation within the SLs of Specification 2.0, " Safety Limits (SLs)," also maintains the above values and assures that offsite dose will be within the 10 CFR 20 and 10 CFR 100 criteria during AOOs.
Accidents are events that are analyzed even though they are not expected to occur during the unit life. The acceptable limit during accidents is that offsite dose shall be maintained within an acceptable fraction of 10 CFR 100 limits. Different accident categories are allowed a different fraction of these limits, based on probability of occurrence. -
Meeting the acceptable dose limit for an accident category is considered having acceptable consequences for that event.
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1 Catawba Units 1 and 2 B 3.3.1-1 Revision No.1 1
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RTS Instrumentation B 3.3.1 BASES BACKGROUND (continued)
The RTS instrumentation is segmented into four distinct but interconnected categories as illustrated in UFSAR, Chapter 7 (Ref.1),
and as identified below:
1.
Field transmitters or process sensors: provide a measurable electronic signal based upon the physical characteristics of the parameter being measured; 2.
Process monitoring systems, including the Process Control System, the Nuclear instrumentation System (NIS), and various field contacts and sensors: monitors various plant parameters, provides any required signal processing, and provides digital outputs when parameters exceed predetermined limits. They may also provide outputs for control, indication, alarm, computer input, and recording; 3.
Solid State Protection System (SSPS), including input, logic, and output bays: combines the input signals fro n the process monitoring systems per predetermined logic and initiates a reactor trip and ESF actuation when warranted by the process monitoring systems inputs; and 4.
Reactor trip switchgear, including reactor trip breakers (RTBs) and bypass breakers: provides the means to interrupt power to the control rod drive mechanisms (CRDMs) and allows the rod cluster control assemblies (RCCAs), or " rods," to fall into the core and shut down the reactor. The bypass breakers allow testing of the RTBs at power.
Field Transmitters or Sensors To meet the design demands for redundancy and reliability, more than one, and often as many as four, field transmitters or sensors are used to measure unit parameters. To account for the calibration tolerances and instrument drift, which are assumed to occur between calibrations, l
statistical allowances are provided in the NOMINAL TRIP SETPOINT.
l The OPERABILITY of each transmitter or sensor can be evaluated when its "as found" calibration data are compared against its documented acceptance criteria.
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Catawba Units 1 and 2 B 3.3.1-2 Revision No.1 i
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RTS Instrumentation B 3.3.1 DASES BACKGROUND (continued)
Trio Setpoints and Allowable Values The NOMINAL TRIP SETPOINTS are the nominal values at which the l
bistables are set. Any bistable is considered to be properly adjusted when the "as left" value is within the band for CHANNEL CALIBRATION tolerance.
The NOMINAL TRIP SETPOINTS used in the bistables are based on the analyticallimits (Ref.1,2, and 3). The selection of these NOMINAL TRIP SETPOINTS is such that adequate protection is provided when all sensor and processing time delays, calibration tolerances, instrumentation uncertainties, instrument drift, and severe environment errors for those RTS channels that must function in harsh environments as defined by 10 CFR 50.49 (Ref. 5) are taken into account. The actual as-left setpoint of the bistable assures that the actual trip occurs in time to prevent an analytical limit from being exceeded.
The Allowable Value accounts for changes in random measurement errors between COTS. One example of Ouch a change in measurement error is drift during the surveillance interval. If the COT demonstrates that the loop trips within the Allowable Value, the loop is OPERABLE. A trip within the Allowable Value ensures that the predictions of equipment performance used to develop the NOMINAL TRIP SETPOINT are still l
valid, and that the equipment will initiate a trip in response to an AOO in time to prevent an analytical limit from being exceeded (and that the consequences of DBAs will be acceptable, providing the unit is operated from within the LCOs at the onset of the AOO or DBA and the equipment functions as designed). Note that in the accompanying LCO 3.3.1, the Allowable Values of Table 3.3.1-1 are the LSSS.
Each channel cf the process control equipment can be tested on line to verify that the signal or setpoint accuracy is within the specified allowance requirements. Once a designated channelis taken out of service for testing, a simulated signal is injected in place of the field instrument signal. The process equipment for the channel in test is then tested, verified, and calibrated. SRs for the channels are specified in the SRs section.
The determination of the NOMINAL TRIP SETPOINTS and Allowable Values listed in Table 3.3.1-1 incorporates all of the known uncertainties applicable for each channel. The magnitudes of these uncertainties are factored into the determination of each NOMINAL TRIP SETPOINT. All l
field sensors and signal processing equipment Catawba Units 1 and 2 B 3.3.1-4 Revision No.1 l
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i RTS Instrumentation B 3.3.1 f
BASES l
i APPLICABLE SAFETY ANALYSES, LCO, and APPLICABILITY (continued) 19.
Automatic Trio Loaic The LCO requirement for the RTBs (Functions 17 and 18) and Automatic Trip Logic (Function 19) ensures that means are provided to interrupt the power to allow the rods to fall into the reactor core. Each RTB is equipped with an undervoltage coil and a shunt trip coil to trip the breaker open when needed. Each train RTB has a bypass breaker to allow testing of the trip breaker while j
the unit is at power. The reactor trip signals generated by the RTS Automatic Trip Logic cause the RTBs and associated bypass breakers to open and shut down the reactor.
The LCO requires two trains of RTS Automatic Trip Logic to be OPERABLE. Having two OPERABLE channels ensures that random failure of a single logic channel will not prevent reactor trip.
These trip Functions must be OPERABLE in MODE 1 or 2 when the reactor is critical. In MODE 3,4, or 5, these RTS trip Functions must be OPERABLE when the RTBs and associated bypass breakers are closed, and the CRD System is capable of rod withdrawal.
3 The RTS instrumentation satisfies Criterion 3 of 10 CFR 50.36 (Ref. 6).
ACTIONS A Note has been added to the ACTIONS to clarify the application of Completion Time rules..The Conditions of this Specification may be entered independently for each Function listed in Table 3.3.1-1. When the Required Channels in Table 3.3.1-1 are specified (e.g., on a per steam line, per loop, per SG, etc., basis), then the Condition may be entered separately for each steam line, loop, SG, etc., as appropriate.
A channel shall be OPERABLE if the point at which the channel trips is i
found more conservative than the Allowable Value. In the event a channel's trip setpoint is found less conservative than the Allowable Value, or the transmitter, instrument loop, signal processing electronics, 1
or bistable is found inoperable, then all affected Functions provided by that char.nel must be declared inoperable and the LCO Condition (s) entered for the protection Function (s) affected. If plant conditions warrant, the trip setpoint may be set outside the NOMINAL TRIP SETPOINT calibration tolerance band as long as the trip setpoint is 4
conservative with respect to the NOMINAL TRIP SETPOINT. If the trip
{
setpoint is found outside of the NOMINAL TRIP SETPOiNT calibration j
tolerance band and non-conservative with respect to the NOMINAL TRIP Catawba Units 1 and 2 0 3.3.1-30 Revision No.1
r RTS instrumentation B 3.3.1
-BASES ACTIONS (continued)
SETPOINT, the setpoint shall be re-adjusted.
When the number of inoperable channels in a trip Function exceed those specified in one or other related Conditions associated with a trip Function, then the unit is outside the safety analysis. Therefore, LCO 3.0.3 must be immediately entered if applicable in the current MODE of operation.
6J.
j Condition A applies to all RTS protection Functions. Condition A addresses the situation where one or more required channels for one or more Functions are inoperable at the same time. The Required Action is to refer to Table 3.3.1-1 and to take the Required Actions for the protection functions affected. The Completion Times are those from the reference ~d Conditions and Required Actions.
B.1 and B.2 Condition 8 applies to the Manual Reactor Trip in MODE 1 or 2. This action addresses the train orientation of the SSPS for this Function. With one channel inoperable, the inoperable channel must be restored to OPERABLE status within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br />. In this Condition, the remaining OPERABLE channelis adequate to perform the safety function.
The Completion Time of 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> is reasonable considering that there are two automatic actuation trains and another manual initiation channel OPERABLE, and the low probability of an event occurring during this interval.
If the Manual Reactor Trip Function cannot be restored to OPERABLE status within the allowed 48 hour5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> Completion Time, the unit must be brought to a MODE in which the requirement does not apply. To achieve this status, the unit must be brought to at least MODE 3 within 6 additional hours (54 hours6.25e-4 days <br />0.015 hours <br />8.928571e-5 weeks <br />2.0547e-5 months <br /> total time). The 6 additional hours are reasonable, based on operating experience, to reach MODE 3 from full power operation in an orderly manner and without challenging unit systems. With the unit in MODE 3, the MODE 1 and 2 requirements for this trip Function are no longer required and Condition C is entered.
Catawba Units 1 and 2 B 3.3.1-31 Revision No.1 m
ESFAS Instrumentation E 3.3.2 BASES BACKGROUND (continued) y provided in the NOMINAL TRIP SETPOINT. The OPERABILITY of each l transmitter or sensor can be evaluated when its "as found" calibration data are compared against its documented acceptance criteria.
Sianal Processina Eauipment Generally, three or four channels of process control equipment are used for the signal processing of unit parameters measured by the field instruments. The process control equipment provides signal conditioning, comparable output signals for instruments located on the main control board, and comparison of measured input signals with setpoints established by safety analyses. These setpoints are defined in UFSAR, Chapter 6 (Ref.1), Chapter 7 (Ref. 2), and Chapter 15 (Ref. 3), if the measured value of a unit parameter exceeds the predetermined setpoint, an output from a bistable is forwarded to the SSPS for decision logic processing. Channel separation is maintained up to and through the input bays. However, not all unit parameters require four channels of i
sensor measurement and signal processing. Some unit parameters provide input only to the SSPS, while others provide input to the SSPS, the main control board, the unit computer, and one or more control systems.
Generally, if a parameter is used only for input to the protection circuits, three channels with a two-out-of-three logic are sufficient to provide the required reliability and redundancy. If one channel fails in a direction that would not result in a partial Function trip, the Function is still OPERABLE with a two-out-of-two logic. If one channel fails such that a partial Function trip occurs, a trip will not occur and the Function is still OPERABLE with a one-out-of-two logic.
Generally, if a parameter is used for input to the SSPS and a control function, four channels with a two-out-of-four logic are sufficient to provide the required reliability and redundancy. The circuit must be able to withstand both an input failure to the control system, which may then require the protection function actuation, and a single failure in the other j
channels providing the protection function actuation. Again, a single j
failure will neither cause nor prevent the protection function actuation.
These requirements are described in IEEE-279-1971 (Ref. 4). The actual number of channels required for each unit parameter is specified in the i
i Catawba Units 1 and 2 B 3.3.2-2 Revision No.1
ESFAS Instrumentation B 3.3.2 BASES BACKGROUND (continued) l Trio Setooints anr' Mb "itde Values The NOMINAL TRIP UETPOINTS ara the nominal values at which the l
bistables are set. Any bistable is co1sidered to be properly adjusted when the "as left" value is within the band for CHANNEL CAllBRATION tolerance.
The NOMINAL TRIP SETPOINTS used in the bistables are based on the analyticallimits (Ref.1,2, and 3). The selection of these NOMINAL TRIP SETPOINTS is such that adequate protection is provided when all sensor I
and processing time delays, calibra; ion tolerances, instrumentation j
uncertainties, instrument drift, and severe environment errors for those ESFAS channels that must function in harsh environments as defined by 10 CFR 50.49 (Ref. 5) are taken into account. The actual as-left setpoint of the bistable assures that the actual trip occurs before the Allowable Value is reached. The Allowable Value accounts for changes in random measurement errors detectable by a COT. One example of such a change in measurement error is drift during the surveillance interval. If the point at which the loop trips does not exceed the Allowable Value, the loop is considered OPERABLE.
i A trip within the Allowable Value ensures that the consequences of Design Basis Accidents (DBAs) will be acceptable, providing the unit is operated from within the LCOs at the onset of the DBA and the equipment functions as designed.
Each channel can be tested on line to verify that the signal processing equipment and setpoint accuracy is within the specified allowance requirements. Once a designated channelis taken out of service for testing, a simulated signal is injected in place of the field instrument signal. The process equipment for the channelin test is then tested, verified, and calibrated. SRs for the channels are specified in the SR l
section.
i The determination of the NOMINAL TRIP SETPOINTS and Allowable Values listed in Table 3.3.2-1 incorporates all of the known uncertainties applicable for each channel. The magnitudes of these uncertainties are factored into the determination of each NOMINAL TRIP SETPOINT. All l
field sensors and signal processing equipment for these channels are x
assumed to operate within the allowances of these uncertainty magnitudes.
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Catawba Units 1 and 2 B 3.3.2-3 Revision No.1
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ESFAS Instrumentation B 3.3.2 BASES APPLICABLE SAFETY ANALYSES, LCO, and APPLICABILITY (continued) valves, and start the NSWS pumps. This function is initiated on a two-out-of-three logic from either NSWS pump pit.
This function must be OPERABLE in MODES 1,2,3, and 4 to ensure cooling water remains available to essential components during a DBA. In MODES 5 and 6, the sufficient time exists for manual operator action to realign the NSWS pump suction, if
. required.
The ESFAS instrumentation satisfies Criterion 3 of 10 CFR 50.36 (Ref.
6).
ACTIONS A Note has been added in the ACTIONS to clarify the application of Completion Time rules. The Conditions of this Specification may be entered independently for each Function listed on Table 3.3.2-1. When the Required Channels in Table 3.3.2-1 are specified (e.g., on a per steam line, per loop, per SG, etc., basis), then the Condition may be entered separately for each steam line, loop, SG, etc., as appropriate.
A channel shall be OPERABLE if the point at which the channel trips is found more conservative than the Allowable Value. In the event a channel's trip setpoint is found less conservative than the Allowable Value, or the transmitter, instrument loop, signal processing electronics.
or bistable is found inoperable, then all affected Functions provided by that channel must be declared inoperable and the LCO Condition (s)
' entered for the protection Function (s) affected. If plant conditions warrant, the trip setpoint may be set outside the NOMINAL TRIP SETPOINT calibration tolerance band as long as the trip setpoint is j
conservative with respect to the NOMINAL TRIP SETPOINT. If the trip j
setpoint is found outside of the NOMINAL TRIP SETPOINT calibration tolerance band and non-conservative with respect to the NOMINAL TRIP SETPOINT, the setpoint shall be re-adjusted.
When the number of inoperable channels in a trip function exceed those specified in one or other related Conditions associated with a trip function, then the unit is outside the safety analysis. Therefore, LCO 3.0.3 should be immediately entered if applicable in the current MODE of operation.
i A.J. _
i Condition A applies to all ESFAS protection functions.
Catawba Units 1 and 2 B 3.3.2-31 Revision No.1 j
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l ESFAS instrumentation B 3.3.2 BASES:
ACTIONS '(continued) l Condition A addresses the situation where one or more channels or trains for one or more Functions are inoperable at the same time. The Required Action is to refer to Table 3.3.2-1 and to take the Required Actions for the protection functions affected. The Completion Times are those from the referenced Conditions and Required Actions.
l B.1. B.2.1 and B.2.2 Condition B applies to manualinitiation of:
Sl; Containment Spray, 4
l Phase A isolation; and Phase B isolation.
i This action addresses the train orientation of the SSPS for the functions listed above. If a channel or train is inoperable,48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> is allowed to return it to an OPERABLE status. Note that for containment spray and j
Phase B isolation, failure of one or both channels in one train renders the I
train inoperable. Condition B, therefore, encompasses both situations.
The specified Completion Time is reasonable considering that there are two automatic actuation trains and another manual initiation train OPERABLE for each Function, and the low probability of an event occurring during this interval. If the train cannot be restored to OPERABLE status, the unit must be placed in a MODE in which the LCO does not apply. This is done by placing the unit in at least MODE 3 within an additional 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> (54 hours6.25e-4 days <br />0.015 hours <br />8.928571e-5 weeks <br />2.0547e-5 months <br /> total time) and in MODE 5 within an additional 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br /> (84 hours9.722222e-4 days <br />0.0233 hours <br />1.388889e-4 weeks <br />3.1962e-5 months <br /> total time). The allowable Completion
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Times are reasonable, based on operating experience, to reach the l
required unit conditions from full power conditions in an orderly manner and without challenging unit systems.
C.1. C.2.1 and C.2.2 Condition C applies to the automatic actuation logic and actuation relays for the following functions:
Sl; Containment Spray; Phase A isolation;
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LOP DG Start Instrumentation B 3.3.5 BASES BACKGROUND (continued)
Trio Setooints and Allowable Values-The NOMINAL TRIP SETPOINTS used in the relays are based on the l
analytical limits presented in UFSAR, Chapter 15 (Ref. 2). The selection of these Trip Setpoints is such that adequate protection is provided when all sensor and processing time delays are taken into account.
The actual as-left setpoint of the relays is normally still more conservative l than that required by the Allowable Value. If the measured setpoint does not exceed the Allowable Value, the relay is considered OPERABLE, Setpoints adjusted in accordance with the Allowable Value ensure that the consequences of accidents will be acceptable, providing the unit is operated from within the LCOs at the onset of the accident and that the equipment functions as designed.
l Allowable Values and NOMINAL TRIP SETPOINTS are specified for each Function in the LCO. The NOMINAL TRIP SETPOINTS are selected to ensure that the setpoint measured by th6 surveillance procedure does not exceed the Allowable Value if the relay is performing as required. A relay shall be OPERABLE if the point at which the relay trips is found more conservative than the Allowable Value. In the event a l
relay's trip setpoint is found less conservative than the Allowable Value, or the transmitter, instrument loop, signal processing electronics, or bistable is found inoperable, then all affected Functions provided by that relay must be declared inoperable and the LCO Condition (s) entered for the protection Function (s) affected. If plant conditions warrant, the trip setpoint may be set outside the NOMINAL TRIP SETPOINT calibration tolerance band as long as the trip setpoint is conservative with respect to the NOMINAL TRIP SETPOINT. If the trip setpoint is found outside of the NOMINAL TRIP SETPOINT calibration tolerance band and non-i conservative with respect to the NOMINAL TRIP SETPOINT, the setpoint shall be re-adjusted. Each Allowable Value and NOMINAL TRIP SETPOINT specified is more conservative than the analytical limit assumed in the transient and accident analyses in order to account for instrument uncertainties appropriate to the trip function. These uncertainties are defined in setpoint calculations.
APPLICABLE The LOP DG start instrumentation is required for the Engineered SAFETY ANALYSES Safety Features (ESF) Systems to function in any accident with a loss of offsite power. Its design basis is that of the ESF Actuation System (ESFAS).
Catawba Units 1 and 2 B 3.3.5-2 Revision No.1
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LOP DG Start instrumentation B 3.3.5 BASES i
APPLICABLE SAFETY ANALYSES (continued) l Accident analyses credit the loading of the DG based on the loss of offsite power during a loss of coolant accident (LOCA). The actual DG start has historically been associated with the ESFAS actuation. The DG loading has been included in the delay time associated with each j
safety system component requiring DG supplied power following a loss of offsite power. The analyses assume a non-mechanistic DG loading, which does not explicitly account for each individual component of loss of power detection and subsequent actions.
The required channels of LOP DG start instrumentation,in conjunction I
with the ESF systems powered from the DGs, provide unit protection in the event of any of the analyzed accidents discussed in Reference 2, in which a loss of offsite power is assumed.
The delay times assumed in the safety analysis for the ESF equipment i
include the 10 second DG start delay, and the appropriate sequencing delay,if applicable. The response times for ESFAS actuated equipment in LCO 3.3.2, " Engineered Safety Feature Actuation System (ESFAS)
Instrumentation," include the appropriate DG loading and sequencing delay. The LOP DG start instrumentation channels satisfy Criterion 3 of 10 CFR 50.36 (Ref. 3).
LCO The LCO for LOP DG start instrumentation requires that three channels per bus of both the loss of voltage and degraded voltage Functions shall
' be OPERABLE in MODES 1,2,3, and 4 when the LOP DG start instrumentation supports safety systems associated with the ESFAS. In MODES 5 and 6, the three channels must be OPERABLE whenever the associated DG is required to be OPERABLE to ensure that the automatic start of the DG is available when needed. Loss of the LOP DG Start Instrumentation Function could result in the delay of safety systems initiation when required. This could lead to unacceptable consequences during accidents. During the loss of offsite power the DG powers the motor driven auxiliary feedwater pumps. Failure of these pumps to start would leave only one turbine driven pump, as well as an increased potential for a loss of decay heat removal through the secondary system.
Catawba Units 1 and 2 B 3.3.5-3 Revision No.1
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LOP DG Start Instrumentation B 3.3.5 BASES APPLICABILITY The LOP DG Start Instrumentation Functions are required in MODES 1, 2,3, and 4 because ESF Functions are designed to provide protection ir these MODES. Actuation in MODE 5 or 6 is required whenever the required DG must be OPERABLE so that it can perform its function on an LOP or degraded power to the vital bus.
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ACTIONS A channel shall be OPERABLE if the point at which the channel trips is found more conservative than the Allowable Value. In the event a j
channel's trip setpoint is found less conservative than the Allowable l
Value, or the transmitter, instrument loop, signal processing electronics.
or bistable is found inoperable, then all affected Functions provided by
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that channel must be declared inoperable and the LCO Condition (s)
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entered for the protection Function (s) affected. If plant conditions warrant, the trip setpoint may be set outside the NOMINAL TRIP SETPOINT calibration tolerance band as long as the trip setpoint is conservative with respect to the NOMINAL TRIP SETPOINT. If the trip setpoint is found outside of the NOMINAL TRIP SETPOINT calibration tolerance band and non-conservative with respect to the NOMINAL TRIP SETPOINT, the setpoint shall be re-adjusted.
Because the required channels are specified on a per bus basis, the Condition may be entered separately for each bus as appropriate.
A Note has been added in the ACTIONS to clarify the application of Completion Time rules. The Conditions of this Specification may be entered independently for each Function listed in the LCO. The Completion Time (s) of the inoperable channel (s) of a Function will be tracked separately for each Function starting from the time the Condition was entered for that Function.
A.1 Condition A applies to the LOP DG start Function with one loss of voltage or degraded voltage channel per bus inoperable.
If one channelis inoperable, Required Action A.1 requires that channel to be placed in trip within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />. With a channelin trip, the LOP DG start instrumentation channels are configured to provide a one-out-of-two logic to initiate a trip of the incoming offsite power.
The specified Completion Time is reasonable considering the Function remains fully OPERABLE on every bus and the low probability of an event occurring during these intervals.
Catawba Units 1 and 2 B 3.3.5-4 Revision No.1 c.
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