Text

Nonproprietary Westinghouse Setpoint Methodology for Protection Sys Turkey Point Units 3 & 4
	ML20072Q579
Person / Time
Site:	Turkey Point
Issue date:	11/30/1990
From:	Ciocca C, Reagan J, Tuley C; WESTINGHOUSE ELECTRIC COMPANY, DIV OF CBS CORP.
To:	;
Shared Package
ML17348A777	List: ML20072Q579;
References
	WCAP-12746, NUDOCS 9012260129
	Download: ML20072Q579 (99)
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WESTINGHOUSE CLASS 3 WCAP - 12746 WESTINGHOUSE SETPOINT METHODOLOGY FOR PROTECTION SYSTEMS TURKEY POINT UNITS 3 & 4 FLORIDA POWER & LIGHT COMPANY November 1990 C. F. Ciocca J. R. Reagan C. R. Tuley WF.5TINGh0VSE ELECTRIC CORPORATION

l TABLE OF CONTENTS Seetion 11. tit P.Hf

1.0 INTRODUCTION

1 2.0 COMBINATION OF ERROR COMPONENTS 2 2.1 Methodology 2 2.2 Sensor Allowances 4 2.3 -Rack Allowances 6

, 2.4 Process Allowances 7 2.5 Measurement and Test Equipment Accuracy 8 3 3.0 PROTECTION SYSTEM SETPOINT METHODOLOGY 9 i

3.1 Margin Calculation 9 3.2 Definitions for Protection System 9 Setpoint Tolerances 3.3 Methodology Conclusion 16 4,0 TECHNICAL SPECIFICATION USAGE 54 4.1 Current Use 54 4.2 Westinghouse _Setpoint Methodology 55 for-STS Setpoints-4.2.1- Rack Allowance 55 4.2.2 Inclusion of "As Measured" 56 Sensor Allowance 4.2.3 Implementation of the- 57 Westinghouse Setpoint Methodology 4.3 Conclusion 61. <

. Appendix A- SAMPLE TURKEY POINT UNITS 3 & 4 SETPOINT 71 TECHNICAL SPECIFICATIONS .

t

)

i 1

l l -

. . . . ... . -- - . -. ,. - - . ..i

LIST OF TABLES la.b.lk lillt EAgf 31 Power Range, Neutron Flux High and Low Setpoints 17 32 Intermediate Range, Neutron Flux 18 33 Source Range, Neutron Flux 19 34 Overtemperature AT 20 35 Overpower AT 22 36 Pressurizer Pressure Low and High. Reactor Trips 24 3-7 Pressurizer Water Level High 25 38 Loss of Flow 26 39 Steam Generator Water Level Low Low, & Low Trip 27 3 10 Steam /Feedwater flow Mismatch 28 3 11 Undervoltage 4,16KV Bus 30 3 12 Underfrequency Trip of RCP Breakers 31 3 13 Turbine Trip Auto Stop 011 Pressure 32 3 14 Containment Pressure - High, Safety injection 33 3-15 Pressurizer Pressure Low, Safety injection 34 3 16' Differential Pressure Between Steam Header & ^

Steam Lines - High, SI 35 j 3 17 High Steam Line Flow SI, Steam Line Isolation 37 3 18 Steam Line Pressure - Low SI, Steam Line isolation 39 3 19 Contait. it Pressure - High High, Spray 40 3 20 Containn.:nt Radioactivity High Particulate, Containment Isolation 41 3 21 Tavg - Low Low, $1, Steam Line Isolation 42 3 22 Containment Radioactivity - High Gaseous, Containment isolation 43 3-23 Reactor Protection System / Engineered Safety features Actuation System Channel Error Allowances 44 Notes for Table 3 23 45 l

l 11 i

LIST OF TABLES (Continued) 11hli 111.11 EASA o 3 24 Overtemperature AT Calculations 48 3 25 Overpower AT Calculations 50 3 26 Steam Generator Level Density Variations 51 3 27 AP Measurements Expressed in Flow Units 52 4-1 Examples of Current STS Setpoint Philosophy 62 4-2 Examples of Westinghouse STS Rack Allowance 62 4-3 Westinghouse Protection System STS Setpoint inputs 65 Notes for Table 4 3 66 iii

LIST OF ILLUSTRATIONS

, Eiouro g g 41 NUREG 0452 Rev. 4 Setpoint Error 63 Breakdown (Analog Process Racks) 42 Westinghouse STS Setpoint Error 64 Breakdown (Analog Process Racks) iv

i 1

j

1.0 INTRODUCTION

i L

in March of 1977, the NRC requested several utilities with Westinghouse Nuclear Steam Supply Systems to reply to a series of 4

questions concerning the methodology for determining instrument

! setpoints. A revised methodology was developed in response to those questions with a corresponding defense of the technique used in determining the overall allowance for each setpoint.

The basic underlying assumption used is that several of the error components and their parameter assumptions act independently, e.g.,

! rack versus sensors and pressure / temperature assumptions. This

allows the use of a statistical summation of the various breakdown

components instead of a strictly arithmetic summation. A direct

{ benefit of the use of this technique is increased margin in the total allowance. For those parameter assumptions known to be interactive, the technique uses the standard, conservative approach -arithmetic summation, to form independent quantities, e.g., drift and calibration error. An explanation of the overall approach is

, provided in Section 2.0.

Section 3.0 provides a description, or definition, of each of the various components in the setpoint parameter breakdown, to allow a clear understanding of the breakdown. Also provided is a detailed

] example of each setpoint margin calculation demonstrating the technique and noting how each parameter.value is derived. In all cases, margin exists between the summation and the total allowance.

Section 4.0 notes what the current Standard Technical Specifications use for setpoints and an explanation of the impact of the Westinghouse approach on them. Detailed examples of how to determine the Technical Specification setpoint values are also provided. An Appendix is provided noting a recommended set of Technical Specifications using the plant specific data in the Westinghouse approach.

1 1

- , . , - . . , - .. ,. , . , _ , . . . . . , , ,, ,.~.-...w.-#ene..... ,,._-.--,--._.--m . , , . . - - . - _ , --. _,e. _, .,,.--,.-...-,-,-.,,m

2.0 COMBINATION OF ERROR COMPONENTS

, 2.1 METHODOLOGY The methodology used to combine the error components for a channel is an appropriate combination of those groups which are statistically independent, i.e., not interactive. Those errors which are not independent are placed arithmetically into groups that are and can then be systematically combined.

The methodology used is the " square root of the sum of the squares" which has been utilized in other Westinghouse reports. This technique, or others of a similar nature, has been used in WCAP 10395(l) and WCAP 8567(2). WCAP 8567 is approved by the NRC noting acceptability of statistical techniques for the application requested. Also, various ANSI, American Nuclear Society, and Instrument Society of America standards approve the use of probabilistic and statistical techniques in determining safety related setpoints(3)(4). The methodology used in this report is essentially the same as that used for V, C. Summer in August, 1982; approved in NUREG 0717, Supplement No. 4(5),

(1) Grigsby, J. M., Spier E. M., Tuley, C. R., " Statistical Evaluation of LOCA Heat Source Uncertainty", WCAP-10395 (Proprietary), WCAP 10396 (Non Proprietary), November, 1983.

(2) Chelemer, H., Boman, L. H., and Sharp, D. R., " Improved Thermal

. Design Procedure," WcAP 8567 (Proprietary), WCAP-8568 (Non Proprietary), July,1975.

(3) ANSI /ANSStandard 58.41979, " Criteria for Technical Specifications for-Nuclear Power Stations."

(4) ISA Standard S67.04,1987, "Setpoints for Nuclear Safety Related Instrumentation Used in Nuclear Power Plants "

(5) NUREG 0717, Supplement No. 4, " Safety Evaluation Report related to the Operation of Virgil C. Summer Nuclear Station, Unit No. 1", Docket No. 50 395, August, 1982.

l 4

i

..,.., , _ - _ . - , . - , . _ . _ , _ _ , . _ _ . , . . . , . _ . _ . . . , , , . _ m___,.. . . . . . . , - _ . . . . . . , . _ _ _ . _ . . . _ _ _ _ _ _ _ _ . _ _ _ . . _ _ . , _ , -

t i

The relationship between the error components and the total error for a channel is noted in Eq. 2.1, CSA = ((PMA)2 + (PEA)2 + (SCA + SMTE + SD)2 + (SPE)2 + (STE)2 +

1 (RCA + RMTE + RCSA + RD)2 + (RTE)2)l/2 + EA + BIAS (Eq. 2.1) where:

CSA =

Channel Statistical Allowance i PMA = !

Process Measurement Accuracy !

PEA =

-Primary Element Accuracy SCA =

Sensor Calibration Accuracy SMTE =

Sensor Measurement and Test Equipment Accuracy SD- -

Sensor Drift SPE =

Sensor Pressure Effects STE = Sensor Temperature Effects RCA =

Rack Calibration Accuracy RMTE =

Rack Measurement and Test Equipment Accuracy RCSA =

{

Rack Comparator Setting Accuracy I RD =

Rack Drift RTE = Rack Temperature Effects EA =

Environmental Allowance i BIAS = Bias ,!

As can be seen in the equation, drift and calibration accuracy allowances are interactive and thus not independent. The

. environmental allowance is.not necessarily' considered interactive.

with all other parameters, but'as an additional degree of l

conservatism is'added to the statistical sum. It should be noted that for this document,.it is assumed that the-accuracy effect on a channel due.to cable degradation'in an accident environment is less !

than 0.1 percent of -span. This magnitude of impact is considered negligible and is not factored into the calculations. An error due

{

to this cause, in. excess of 0.1 percent of span is directly added as an environmental error. '

1 i

3 i

The Westinghouse setpoint methodology, i.e., square root of the sum of the squares, results in a 95% probability with the confidence

, level defined by the appropriate combination of the various confidence levels of the input values. With the exception of the PMA, EA and RD terms, all uncertainties assumed are at least 2 o values.

Calibration accuracies are the extremes of the ranges and are better than 2 o values. Rack drift is assumed based on a survey of reported plant LERs and is considered conservative. PMA values tre determined or calculated on a conservative basis and are believed to bs at least 2 o values. Transmitter ambient, steady state values are bued on vendor specification data and are considered 2 o values. Transmitter EA values are based on vendor specificatio7 data and are rtoorted by the vendor with a high confidence. The values noted in this document, with respect to streaming, are bounding, based on available data, and are treated in a conservative manner.

Temperature streaming in the hot and cold legs is under Westinghouse review and no further impact on the trip setpoints is anticipated.

2.2 SENSOR ALLOWANCES Five parameters are considered to be sensor allowances, SCA, SMTE, SD, STE, and SPE (see Table 3 23). Of these parameters, two are considered to be statistically independent, STE and SPE, and three are considered interactive, SCA, SMTE and SD. STE and SPE are considered to be independent due to the manner in which the instrumentation is checked, 1.e., the instrumentation is calibrated and drift determined under conditions in which pressure and temperature are assumed constant. An example of this would be as follows; assume a sensor is placed in some position in the containment during a refueling outage. After placement, an instrument tec5nician calibrates the sensor. This calibration is performed at ambient pressure and temperature conditions. Some time later with the plant shutdown, an instrument technician checks for sensor drift. Using the same technique as for calibrating the 4

l

1 1

sensor, the technician determines if the sensor has drifted. The conditions under which this determination is made are again at

, ambient pressure and temperature conditions. Thus the temperature and pressure have no impact on the drift determination and are, 3

therefore, independent of the drift allowance.

SCA, SMTE and SD are considered to be interactive for the same reason s that STE and SPE are considered independent, i.e., due to the manner in which the instrumentation is checked. Instrumenution calibration techniques use the same process as determining instrument drift, that is, the end. result of the two is the same. When calibrating a sensor, the sensor output is checked to determine if it is representing accurately the input. The same is performed for a i

determination of the sensor drift.- Thus unless *as left/as found" data is recorded and used, it is impossible to determine the differences between calibration errors and drift when a sensor is checked the second or any subsequent time. Based on this reasoning, SCA, SMTE and SD have.been added to form an independent group which

.is then factored into Equation 2.1. An example of the impact of this treatment for a level. transmitter is (sensor parameters only):

+a,c

-- SCA= =

F SMTE =

SPE --

. STE =

SD = ,

excerpting the sensor portion of Equation 2.1 results in;

((SCA+SMTE+50)2+(SPE)2+(STE)2)l/2

.( ]+a,c = 2.12%-

- Assuming no interactive effects for any of the parameters results in the following:

S 3e- p--.,r m, , -,-v.m --,w., e--.ev,e.- . , - - . , v-- ,

,,.ir- r 3.r., -. y,,.--y.-,, - - - , =-,,.,,,,,,,,,,-.,r-.--,,,---e,

j I

! l 1 1 1

, ((SCA)2 + (SMTE)2 + (50)2 + (SPE)2 + (STE)2)l/2 (Eq. 2.2) I

( )+6 C 1.41%

[ Thus it can be seen that the approach represented by Equation 2.1,

! which accounts for interactive parameters, results in a more conservative summation of the allowances.

i

~

2.3 RACK ALLOWANCES i Five parameters, as noted by Table 3 23, are considered to be rack ;

i allowances, RCA, RMTE, RCSA, RTE, and RD. Four of these parameters are considered to be-interactive (for much the same reason outlined for sensors in 2.2), RCA, RMTE. RCSA, and RD. When calibrating or

-determining drift in the racks for a specific channel, the processes are performed at essentially constant temperature, i.e., ambier,t

, temperature. Because of this, the RTE parameter is considered to be independent of any factors for calibration or drift. However, the same cannot be said for the other rack parameters. As noted in 2.2, when calibrating or determining drift for a channel, the same end result is desired, that is, at what point does the bistable change state. After initial calibration, without recording and using "as left/as found' data, it is not possible to distinguish the difference between a calibration error, rack drift or a comparator setting error. Based on this logic, these factors have been added to form an independent group. This group is then factored into Equation 2.1.

The impact of this approach (formation of an independent group based on interactive components) is significant. For a level transmitter channel, using the same approach outlined in Equations 2.1 and 2.2 results in the following:

6

+a,c RCA =

RMTE =

RCSA =

RTE =

RD =

excerpting the rack portion of Equation 2.1 results in; s

((RCA + RM1E + RCSA + RD)2 + (RTE)2)l/2

( ]+a,e = 1.94%

Assuming no interactive effects for any of the parameters yields the following less conservative results;

((RCA)2 + (RMTE)2 + (RCSA)2 + (RD)2 + (RTE)2)l/2 (Eq. 2.3)

( ]+a,c = 1.26%

Thus, the impact of the use of Equation 2.1 is even greater in the area of rack effects than for the sensor. Therefore, accounting for interactive effe.:ts in the treatment of these allowances insures a conservative result.

2.4 PROCESS All0WANCES Finally, the PMA and PEA parameters are considered to be independent of both sensor and rack parameters. PMA provides allowances for the non-instrument related effects, e.g., neutron flux, calorimetric power error assumptions, fluid density changes, and temperature stratification assumptions. PMA may consist of more than one i.Vependent error allowance. PEA accounts for errors due to metering devices, such as elbows and venturis. Thus, these parameters have been factored into Equation 2.1 as independent quantities.

7 1

s

)

1 l-

2.5 MEASUREMENT AND TEST E0VIPMENT ACCURACY i

Westinghouse believes that some of the equipment used for calibration 4

and functional testing of the transmitters and racks may not meet SAMA standard PMC 20.1 1973(I) with regards to test equipment L accuracy of 10 percent or less of the calibration accuracy (referenced in 3.2.6.a and 3.2.7.4. of this report). This requires the inclusion of the accuracy of this equipment in the basic equations 2.1 and 3.1. Based on information provided by the plant, these additional uncertainties are included in the calculations (as

) noted on the tables included in this report) with some impact on the final results. On Table 3 23, the values of SMTE and RMTE are identified explicitly.

i, i

(1) Scientific Apparatus Manufacturers Association, Standard PMC i 20.1-1973, " Process Measurement and Control Terminology."

~

4 8

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

L0 PROTECITON SYSTEM SETPOINT JJQQQLQfd 3.1 MARGIN CALCULATION As noted in Section 2 Westinghouse utilizes the square root of the sum of the squares for sumation of the various components of the channel breakdown. This approach is valid where no dependency is present. An arithmetic sumation is required where an interaction between two parameters exists. The equation used to determine the margin, and thus the acceptability of the parameter values used, is:

Margin TA - ((PMA)2 + (PEA)2 + (SCA + SMTE 4 SD)2 + (SPE)2 + (STE)2 (RCA + RMTE + RCSA + RD)2 + (RTE)2)l/2 - EABias (Eq. 3.1) where:

TA = Total Allowance (Safety Analysis 1.imit Nominal Trip Setpoint),and all other parameters are as defined for Equation 2.1.

Using Equation 2.1, Equation 3.1 may be simplified to:

Margin - TA CSA (Eq. 3.2)

Tables 3 1 through 3 22 provide individual channel breakdown and CSA calculations for all protection functions utilizing Westinghouse -

Hagan 7100 analog process rack equipment, or Westinghouse Eagle digital equipment. Table 3 23 provides a summary of the previous 22 tables and includes Safety Analysis and Technical Specification values, Total Allowance and Margin.

l 3.2 DEFINITIONS FOR PROTECTION SYSTEM SETPOINT TOLERANCES To insure a clear understanding of the channel breakdown used in this report, the following definitions are noted:

9

i

1. Trio Accuraev 1

The tolerance band is the region that contains the highest expected i value of the difference between (a) the desired trip point value of a j process variable and (b) the actual value at which a comparator trips l

(and thus actuates some desired result). This is the tolerance band, f in percent of span, within which the complete channel must perform its intended trip function. It includes comparator setting accuracy, channel accuracy (including the sensor) for each input, and i

i environmental-_ effects on the rack mounted electronics. It comprises all instrumentation errors howcVer, it does not include process '

measurement accuracy.

\ 2. Process Measurement Accurnev Includes plant variable measurement errors up to but not including

- -the sensor. Examples are the effect of fluid stratification on temperature measurements and the effect of changing fluid density on

! level measurements. "

1' -

. 3. Actuation Accuraev .

Synonymous with trip accuracy, but used where the word " trip" does i not apply.

4. -Indication Accuracy The-tolerance band is the region that contains the highest expected value of the difference between (a) the value of a process variable read on an indicator or. recorder and (b) the actual value of that process variable. An indication must fall within this tolerance band. It includes channel accuracy, accuracy of readout devices, and rack environmental effects, but not process measurement accuracy. It does include a controlled environment for the readout device.

10 i' l c,--- n--,--,---.,r. ,--,m--,-, , , , -. . - . m,v

l 1

5. Channel Accuraev 5

l: The accuracy of an analog or digital channel which includes the accuracy of the primary element and/or transmitter and modules in the j

' chain where calibration of modules intermediate in a chain is allowed to compensate for errors in other modules of the chain. Rack

environmental effects are not included here to avoid duplication due to dual inputs, however, normal environmental effects on field mounted hardware is included.

I 6. Sensor Allowable Deviation j _The accuracy that can be expected in the field. It includes drift, L

temperature effects, field calibration and for the case of Ap transmitters, an allowance for the effect of static pressure variations.

'l a.

I The tolerances are as follows:

a. Reference (calibration) accuracy - ( )+a,c unless other data indicates more inaccurar,y. This accuracy is the SAMA reference accuracy as defined in SAMA standard PMC20.1-1973(I).

- b. Measurement and Test Equipment accuracy usually included as an integral part of (a), Reference (calibration) accuracy, when~less than 10 percent of the value of (a).

Forequipment(DVM,pressuregauge,etc.)usedtocalibrate' the sensor with larger uncertainty values, a specific allowance is made.

(1) Scientific Apparatus Manufacturers Association, Standard PMC 20.1 1973, " Process Measurement and Control Terminology."

i a

s-11

, - , , , ,~, , --,-r-., , , , . n.n--- -.,,....n... ~,v..,,,,

c. Temperature effect ( )+a,e based on a nominal 4

temperaturecoefficientof( )***C/100 0F and a 0

maximum assumed change of 50 F (typical for Westinghouse l suppliedequipment). Specific calculations for Rosemount i

transmitters reflect model and range code requirements. For

' those devices located in containment, a maximum assumed 1 0

change of 60 F per SECL 88 434 for containment temperature increase to 1300 F is utilized for protection system l setpoints,

d. Pressure effect usually calibrated out because pressure is constant.- If not constant, a nominal ( ]+a,c is used. Present data indicates a static pressure effect of approximately [ )+a,c/1000 psi for Westinghouse supplied equipment. Specific calculations for Rosemount transmitters reflect model and range code requirements, e .. Drift change in input output relationship over a period of time (12 - 18 months)* at reference conditions (e.g.,

constanttemperature-[- )+a,c e7 gpan), Sp,cgfje calculations for Rosemount transmitters reflect model and range code requirements for an 18 month period of time.

7. Rack Allowable Deviation The tolerances are as follows:

r

a. Rack Calibration Accuracy The accuracy that can_be expected during a calibration at reference conditions. .This accuracy is the SAMA reference NRC Generic Letter 89-14,8/21/89, allows a surveillance internal extension of up to 25%. '

12

1 l

accuracy as defined in SAMA standard PMC 20.1-1973(I).

3 For an analog channel, this includes all modules in a rack i

andisatotalof[ ]+a c of span, assuming the chain i

of modules is tuned to this accuracy. For simple loops where a power supply (not used as a converter) is the only j

rack module, this accuracy may be ignored. All analog process modules individually must have a reference accuracy within[ ]+a,c of span.

L >

For a digital channel, this accuracy represents calibration of the signal conditioning A/D converter providing input to the central processing unit. Each signal conditioning -

A/D converter module is calibrated to within an accuracy of

[ )+a,b,c of span (for functions with rack inputs of I

~ 4 20 mA), or [ ]+a,b.c of span (for functions with l RfD rack inputs).

. b. Measurement and Test Equipment Accuracy is usually included as an integral part of (a), Reference (calibration) accuracy, when less than 10 percent of the value of (a). For. equipment (DVM, current source voltage source, etc.) used to calibrate the racks with larger-uncertainty values, a specific allowance is made.

- c. Rack Environmental Effects Includes effects of temperature.. humidity, voltage and frequency changes of.which temperature-is the most (1) Scientific Apparatus Manufacturers Association, Standard PMC 20.1 1973, ' Process Measurement and Control Terminology".

f 13-t

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

significant. Anaccuracyof( )+a,c of span is used foranalogracks,and[ }+a,b.c i

is used for digital racks, which considers a nominal ambient temperature of 700F with extremes to 40 0F and 120 0F for short periods of time.

> d. Rack Drift Instrument channel drift change in input output relationship over a period of time at reference conditions (e.g., constant temperature) 1 1.0 percent of span for

~

analog racks a1d ( )+a.c span for digital racks.

The time perioi1 applicable for taalog racks is 30 days. The i

time period applicable for digital racks is 92 days, i

I

e. Rack Comparator Setting Accuracy for an analog channel, assuming an exact electronic input, (notethatthe"channelaccuracy"takescareofdeviations from this ideal), the tolerance on the precision with which a comparator trip value can be set, within such practical

. constraints as time and effort expended in making the s6tting.

T The tolerances assumed for Turkey Point Units _3 & 4 are as follows for the Westinghouse - Hagan 7100 analog process 1 racks:

(a) Fixed setpoint with a single input - [ ]+"'0 of span accuracy. This assumes that comparator nonlinearities e are compensated by the setpoint.

(b) Dual input - an additional ( ]+a,c of span must be added for comparator nonlinearities between two inputs.

Total accuracy is [ ]+a,c of span.

14 1

- - . . - .- - . . . . . _ . _ . - _ . . _ . _ . _ - _ - _ _ _.__,.m......_

- .,m.. , , _ . - - ,

1 j' Digital channels do not have an electronic comparator, therefore no l uncertainty is included for this term for these channels. .

Note: The following' four definitions are currently used in the Standardized Technical Specifications (STS).

8. Nominal Safety System Settina The desired setpoint for the variable, initial calibration and subsequent recalibration should be made at the nmninal safety system setting (" Trip Setpoint' in Turkey Point Units 3 & 4 Technical Specifications).

9. Limitino Safety System Settina A setting chusen to prevent exceeding a Safety Analysis 1.imit

(* Allowable Values" in Turkey Point Units 3 & 4 Technical Specifications). Violation of this setting may represent a Technical Specification violation (depending on the condition of all sspects of the instrumentation and analytical margin).

10. Allowance for instrument Channel Orift The difference between (8) and (9) taken in the conservative direction,

11. Safety Analysis Limit l

The setpoint value assumed in safety analyses.

1

12. Total Allowable Setooint Deviation Maximum setpoint_ deviation from a nominal due to instrument hardware l

effects.

t 15

1 l

l 3.3 METHODOLOGY CONCLUSION The Westinghouse setpoint methodology, i.e., square root of the sum of the squares, results in a 95% probability with the confidence level defined by the appropriate combination of the various confidence levels of the input values. With the exception of the PMA, EA and RD terms, all uncertainties assumed are at least 2 o values.

Calibration accuracies are the extremes of the ranges and are better than 2 o values. Rack drift is assumed based on a survey of reported plant LERs and is considered conservative. PMA values are determined or calculated on a conservative basis and are believed to be at least 2 o values. Transmitter ambient, steady state values are based on vendor specification data and are considered 2 o values. Transmitter EA values are based on vendor specification data and are reported by the vendor with a high confidence. The values noted in this document, with respect to streaming, are bounding, based on available data, and are treated in a conservative manner.

Temperature streaming in the hot and cold legs is under Westinghouse review and no further impact on the trip setpoints is anticipated.

16

l i

TABLE 3 1 POWER RANGE, NEUTRON FLUX HIGH AND LOW SETPOINTS Parameter Allowance

Process Measurement Accuracy

+a c - -

48.C Primary Element Accuracy Sen or Calibration

+a.c Sensor Pressure Effects Sen or Temperature Effects Sen or Orift

],,,e Environmental Allowance Rack Calibration Rack Accuracy Measurement & Test Equipment Accuracy Comparator Rack Temperature Effects Rack Drift

In percent span (120% Rated Thermal Power)

Channel Statistical Allowanco =

+4,C 17

. 1 TABLE 3 2 INTERMEDIATE RANGE, NEUTRON FLUX l

Parameter _ Allowance

I j Process Measurement Accuracy i

~

+a.C

- +a.C 4

a -

Primary Element Accuracy Sensor Calibration

[- )+ac 1

, Sensor Pressure Effects

-Sensor Temperature Effects

[ 3+a,c Sensor Orift

[ )+a,c Environmental Allowance

- Rack Calibration

, -Rack Accuracy

Measurement & Test Equipmea' Accuracy Comparator One input !

' Rack Temperature Effects Rack Drift-d i 5% RTP

.l i

In percent span (conservatively assumed to be-120%' Rated Thermal Power)

. Channel Statistical Allowance -

+a,c-EE 1 "

18

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

i 4 ;

TABLE 3 3 '

SOURCE RANGE, NEUTRON FLUX 5

i' Parameter

. Allowance *

Process Measurement Accuracy 4 4, C -

- +8,C

~

Primary Element Accuracy I

Sensor Calibration

( )+a,c- .

Sensor Pressure Effects SenorTemperatureE{ggts

-l Sensor Drift

[ )+a,c ;

Environmental Allowance Rack Calibration Rack Accuracy 1 Measurement & Test Equipment Accuracy Comparator-One input-Rack Temperature Effects I

'RackDrifg 3 x 10 CPS i"

a.

In percent' span (1 x 106 CPS)

Channel Statistical Allowance =

+a.c i-,

L 19

TABLE 3 4 OVERTEMPERATURE AT Ettameter Allowance

Process Measurement Accuracy

--+a,C -

-+aC AT -

61 -

bl -

Tavg -

Primary Element Accuracy Sensor Calibration

+a,C AT -

Pressure -

Measurement & Test Equipment Accuracy Pressure - [ )**+a,c Sensor Pressure Effects Sensor Temperature Effects Pressure - [ ]**+a,c Sensor Drift

-+a,c bT -

Pressure -

Bias Environmental Allowance Rack Calibration (Digital Process Racks)

AT - [ ]+8'C Pressure Al Measurement & Test Equipment Accuracy AT Pressure Al Y

20

TABLE 3 4 (Continued)

OVERTEMPERATURE AT Parameter Allowance *

~ ~

Total Rack Calibration Accuracy

~

-+a,c Rack Temperature Effects AT - [ ]+a,c Pressure Al Rack Orift AT - [ )+a c Pressure AI In percent span (Tavg - 750F, pressure 1000 psi, power - 120% RTP AT - 750 F, AI - 100% AI)

- See Table 3-24 for gain and conversion calculations

Numbet af Hot leg RTDs used

1. Number of Cold leg RTDs used

+a,c Channel Statistical Allowance -

-+a,c i

21 l

TABLE 3 5 Parameter Allowance

Process Measurement Accuracy

- +a,C

-+a'c Ai Tayg -

0 imacy Element Accuracy Sensor Calibration AT - ( )+a,c Sensor Pressure Effects Sensor Temperature Effects Sensor Drift AT - ( )+a,c Environmental Allowance Rack Calibration (Digital Process Ratu)

AT - ( )+a,c Heasurement & Test Equipment Accuracy AT Total Rack Calibration Accure:y

+a,c AT -

Rack Tempcrature Effects AT - ( )+a,c Rack Drift AT - ( )+a,c 22

TABLE 3 5 (Continued)

OVERPOWER AT In percent span (Tavg - 75 0F, AT - 75 F, 0 Power - 120% RTP)

Number of Hot hg RTDs used

1. Number of Cold Leg RTDs used 0 [ )+a,c Channel Statistical Allowance =

+a,c

~

23

TABLE 3 6 PRESSURIZER PRESSURE LOW AND HIGH, REACTOR TRIPS Parameter Allowance *

+a,c Process Measurement Accuracy low High Primary Element Accuracy Sensor Calibration Measurement & Test Equipment Accuracy Sensor Pressure Effects Sensor Temperature Effects Sensor Drift '

Environmental Allowance

-Rack Calibration Rack Accuracy Measurement & Test Equipment Accuracy Comparator One inp'Jt Rack Temperature Effects Rack Drift In percent span (1000 psi)

Channel Statistical Allowance -

+a,c 24

TABLE 3-7 r

PRESSURIZER WATER LEVEL - HIGH .

3 Parameter Allowance

Process Measurement Accuracy

[ ]+a,C. '

Primary Element Accuracy Sensor Calibration Measurement & Test Equipment Accuracy Sensor. Pressure Effects Sensor Temperature Effects

. Sensor Orift Environmental. Allowance t

Rack Calibration (Digital Process Racks)

Rack Accuracy _ _

i

~ Measurement &lTest Equipment Accuracy Rack Temperature Effects Rack Orift. ,

- - i

'l

'finLpercent' span".(100% span)

Channel' Statistical Allowance --

i

+a, c g

i I

l ::

u p ,

l 25 1

TABLE 3 8 LOSS OF FLOW '

Parameter Allowance

Process Measurement Accuracy

+a,c - -

+a,c Primary Element Accuracy

[ )+a,c Sensor Calibration

( )+a,c Sen or Pressure Effects Sen or Temperature Eff Sensor Drift

[ j+a,c Environmental Allowance Rack Calibration Rack Accuracy [ ]+a,c Measurement & Test Equipment Accuracy [ ]+a,c Comparator One input [ ]+a,c Rack Temperature Effects

( )+a,c Rack Drift 1.0% AP span j

In percent flow span (120% Thermal Design Flow) % AP span converted to flow span via Equation 3-28.8, with Fmax = 120% and FN = 100%

Channel Statistical Allowance -

+a,c 26

{

1

TABLE 3 9

-STEAM GENERATOR WATER LEVEL 1.0W LOW, & LOW TRIP Parameter Allowance

Process Measurement Accuracy -

-+a,c level Density variations with load **

Primary Element Accuracy Sensor Calibration Accuracy level Measurement & Test Equipment Accuracy Level Sensor Pressure Effects Level Sensor Temperature Effects Level Sensor Drift Level Environmental Allowance Rack Calibration Rack Accuracy Measurement & Test Equipment Accuracy Rack Comparator Setting Accuracy Rack Temperature Effects Rack Drift In percent span (100% span)

- See Table 3-26.

Channel Statistical Allowance =

+a,c m

27 l

l

l TABLE 3 10 STEAM / FEE 0 WATER FLOW MISMATCH Parameter Allowance

Process Measurement Accuracy '

+a,c

+8,C J

Primary Element Accuracy

( )+a,c Sensor Calibration -

-+a,c Steam Flow Feed Flow Steam Pressure Measurement & Test Equipment Accuracy

-+a,c Steam Flow Feed Flow Steam Pressure Sensor Pressure Effects

+a,c Steam Flow Feed Flow Sensor Temperature Effects

+a, c Steam Flow Feed Flow Steam Pressure Sensor Drift

+a,c Steam Flow Feed Flow Steam Pressure Environmental Allowance Rack Calibration Rack Accuracy Steam Flow Feed Flow Steam Pressure [ ]+a,c 28 l

_ _ _ _ _ _ _ _ _ _ _ _ _ - _ - _ _ - -- - - - - - - ~ ~ ~ - - ' - ^ - ' ' ^ ' - - ' - - ~ ' - - - - - ~

-l TABLE 3-10(Continued) i i

STEAM /FEEDWATER FLOW MISMATCH Parameter Allowance

Measurement.&-Test Equipment Accuracy Steam Flow Feed Flow Steam Pressure ( )+a,c

- Comparator.

Two inputs Rack Temperature Effects Rack Drift i Steam Flow Feed Flow Steam Pressure [ ]+a,c In percent -span (120% nominal steam flow) a

% AP span converted to flow span via Eq. 3-28,8,

+a,c !

}

)

Channel Statistical Allowance-

+a,c

-l

-. )

29 l-

TABLE 3 11 UNDERVOLTAGE 4.16KV BUS Parameter Allowance

Process Measurement Accuracy

~ ~

Primary Element Accuracy Sensor Calibration Sensor Pressure Effects Sensor Temperature Effects Sensor Orift Environmental Allowance Rack Calibration Rack Accuracy Measurement & Test Equipment Accuracy Comparator Rack Temperature Effects

. Rack Drift In percent span (1040 VAC)

Channel Statistical Allowance -

+a,c 4

30

TABLE 3 12 UNDERFREQUENCY TRIP 0F RCP BREAKERS p

~ ~

Process Measurement Accuracy Primary Element Accuracy Sensor Calibration Sensor Pressure Effects Sensor Temperature Effects Sensor Drift Environmental Allowance Rack Calibration Rack Accuracy Measurement & Test Equipment Accuracy Comparator Rack Temperature Effects Rack Drift In percent span (6.7 HZ AC)

Channel Statistical Allowance -

+a,c 31

TABLE 3 13 TURBINE TRIP AUTO STOP OIL PRESSURE Parameter Allowance *

+a,c Process Measurement Accuracy Primary Element Accuracy Sensor Calibration Measurement & Test Equipment Accuracy Sensor Pressure Effects Sensor Temperature Effects Sensor Drift Environmental Allowance Rack Calibration Rack Accuracy Measurement & Test Equipment Accuracy Comparator One input Rack Temperature Effects Rack Drift /

In percent span (58 psig)

Channel Statistical Allowance -

+a,c 32

E l

i r

TABLE 3-14 CONTAINMENT PRESSURE HIGH, SI Parameter'

~

Allowance

Process Measurement Accuracy -- + a . c Primary Element Accuracy i I

Sensor Calibration Measurement & Test' Equipment Accuracy 1

Sensor Pressure Effects ,

Sensor Temperature Effects Sensor Drift Environmental Allowance Rack Calibration-Rack Accuracy

-Measurement & Test. Equipment Accuracy +

Comparator i-10ne input Rack 1 Temperature Effects Rack Drift-3

- I

..- In percent. span (100-psig)-

' Channel StatisticalfAllowance =

~ r- --

+a,c 4 t.

1 L

1 4

t 33 1

i l

[ TABLE 3 15 PRESSVRIZER PRESSURE - LOW, SAFETY INJECTION Parameter A'3wance*

-+a,c Process Measurement Accuracy Primary Element Accuracy '

Sensor ,alibration Measurement & Test Equipment Accuracy Sr . Or Pressure Effects densor Temperature Effects Sensor Drift Environmental Allowance Rack Calibration

~ Rack Accuracy Measurement & Test Equipment Accuracy Comparator One input Rack Temperature Effects Rack Drift In percent-span (1000 psig)

Chann.el Statistical' Allowance =

+a,c 34

TABLE 3-16 DIFFERENTIAL PRESSURE BETWEEN STEAM HEADER & STEAM LINES - HIGH, SI Parameter Allowance *

~ ~

Process Measurement Accuracy Primary Element Accuracy Sensor Calibration Steamline Header Measurement & Test Equipment Accuracy Steamline Header Sensor Pressure Effects Sensor Temperature Effects Steamline Header Sensor Drift Steamline Header Environmental Allowance Rack Calibration Rack Accuracy Steamline Header Measurement & Test Equipment Accuracy Steamline Header Comparator Two inputs Rack Temperature Effects Rack Drift Steamline Header 35 i

TABLE 3 16 (Continued)

DIFFERENTIAL PRESSURE BETWEEN STEAM HEADER & STEAM LINES - HIGH, SI

In percent span ( = 1400 psig)

Channel Statistical Allowance =

~

+a,C 36

TABLE 3-17 HIGH STEAM LINE FLOW-SI, STEAM LINE ISOLATION Paraceter Allowance =

Process Measurement Accuracy

+a,c

-+a,c Primary Element Accuracy Sensor Calibration -

-+a,c Steam Flow Turbine Pressure Measurement & Test Equipment Accuracy

~+'

Steam Flow Turbine Pressure Sensor Pressure Effects

~

Steam Flow Sensor Temperature Effects

~

Steam Flow Turbine Pressure Sensor Drift -

-+a,c Steam Flow Turbine Pressure Environmental Allowance Rack Calibration Rack Accuracy Steam Flow [ )+a,c Turbine Pressure 6

37

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

3 3

' TABLE 3 17-(Continued)

HIGH STEAM LINE FLOW SI, STEAM LINE ISOLATION Parameter Allowance

Measurement & Test Equipment Accuracy

- +a,c Steam Flow ( )+a,c Turbine Pressure Comparator- --

+a,c ;

i Steam Flow-Turbine Pressure - -

l Rack Temperat'are Effects ( )+a,c Rack Drift Steam Flow )+a,c ,

Turbine Press (ure L

i In percent span. (120% nominal . steam' flow)

% AP span converted to flow span via Eq. 3-28.8, !

1 where Fmax - 120%'_FN - 100%

Channel StatisticalLAllowance-

+a , c -

i

)

I i 38 4

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

l l

TABLE 3-18' STEAM LINE PRESSURE - LOW SI, STEAM LINE ISOLATION.

i

~ Parameter '

Allowance

Process Measurement Accuracy '

Primary Element Accuracy

' Sensor Calibration. !

Measurement & Test Equipmen_t Accuracy '

Sensor Pressure' Effects Sensor Temperature Effects

' Sensor Drift Environmental Allowance

. Rack Calibration Rack Accuracy i Measurement & Test Equipment Accuracy Comparator:

0ne input-Rack Temperature Effects Rack Drift'

tInpercent' span (1400psig)

Channel Statistical. Allowance -

q+a,c I

39

TABLE 3 19 CONTAINMENT PRESSURE - HIGH HIGH, SPRAY Parameter Allowaneg*

~ ~

Process Measurement Accuracy Primary Element Accuracy Sensor Calibration Measurement & Test Equipment Accuracy Sensor Pressure Effects Sensor Temperature Effects Sensor Drift Environmental Allowance Rack Calibration Rack Accuracy Measurement & Test Equipment Accuracy Comparator One input Rack Temperature Effects Rack Drift In percent span (100 psig)

Channel Statistical Allowance -

+a c a

40

l l TABLE 3 20 1

CONTAINMENT RADIOACTIVITY - HIGH PARTICULATE, CONTAINMENT ISOLATION Parameter All owance*-

+a,c Pro ess Measurement Accuracy Primary Element Accuracy Sensor Calibration Measurement & Test Fquipment Accuracy Sensor Pressure Effects Sensor Temperature Effects Sensor Drift Environmental Allowance Rack Calibration Rack Accuracy Neasurement & Test Equipment Accuracy Compi.rator 0'ie input Rack Temperature Effects Rack Drift Inpercentspan(999990.0 CPM)

Channel Statistical Allowance =

+a,c 41

l l

TABLE 3-21 TAVG - LOW-LOW,SI, STEAM LINE ISOLATION Earameter Allowance *

+a,c Process Measurement Accuracy [ ]'a,c Primary Element Accuracy Sensor Calibration Accuracy

( )+a,c Sensor Pressure Effects Sensor Temperature Effects Sensor Orift

[ ]+a c Environmental Allowance Rack Calibration (D tal Process Racks)

Heasurement & Test Equipment Accuracy g

Total Rack Calibration Accuracy

+a,c Rack Temperature Effects Rack Drift In percent span (750F)

Number of Hot Leg RTDs used

1. Number of Cold Leg RTDs used 0 [ )+a,c

~

Channel Statistical Allowance =

+a3c 42

TABLE 3-22 CONTAINMENT RADI0 ACTIVITY - HIGH GASE0US, CONTAINMENT ISOLATION Parameter-Allowance *

-- + a , c Pro ess Measurement Accuracy Primary Element Accuracy 3 Sensor Calibration Measurement'& Test Equipment Accuracy

-Sensor Pressure Effects Sensor Temperature Effects i

Sensor Drift Environmental Allowance i

Rack Calibration Hack Accuracy Measurement & Test Equipment Accuracy q

Comparator One input <

-Rack-Temperature Effects Rack Drift y

In percent spaa-(49990,0 CPM)

Channel. Statistical Allowance-=

_.+a,c 43

. _ _ , , g -9

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NOTES FOR TABLE 3-23

'l. All values in percent span.

2. As noted in FSAR.

3. As noted in Tables 2.2-1 and 3.3-3 of plant Technical Specifications.

4, Included in ( ]+a,c

5. Not specifically used in the Safety Analysis.

6. As noted ir. Table 2.2-1 Note 1 of Plant Technical Specifications shown below.

TABLE 2.2-1 TABLE NOTATION REACTOR TRIP SYSTEM INSTRUMENTATION TRIP SETPOINTS NOTE 1: OVERT!MPERATURE AT 1 '

AT((1 " ++ 771 U bI )(I I

I bI) i AT, (K3 4

- K II{ *" I+bI 5 7 U )(T(II 6

I b)) - T'] + K (P - P') - f (AI))

g 3 3 2 3 Where: AT = Measured AT by RTD instrurrentation; 1+Ii g g 7$ = Lead / Lag compensator on measured AT; 2

7 ,7 = Time constants utilized in the lag compensator 3 2 lor AT; 73 = 8 secs. 27

3 *' -

1 (g , 7 $) = The function generated by the rate-lag controller for Tavg dynamic compensatton; AT, 1 Indicated Delta-T at RATED THERMAL. POWER:

K 3

1 1.095; K

2 1 0.0107/0F; I+T1 4 g,7$ = The function generated by the lead-lag controller for Tavg dynamic compensation:

74.7$ = Time constants utilized in the lead-lag controller for Tavg, 74 = 25 secs., 75 = 3 secs.;

i = Average temperature F:

a 1

= Lag compensator on measured T,yg; I+7b6 O

T' 1 574.2 r (hominal T at RATED THERMAL POWER) 45

i NOTES FOR TABLE 3 23 (Continued)

TABLE 2.2 1 (continued)

NOTE 1: OVERIEMPERATURE AT (continued) !

K 3

3 0.000453/psig: ;

7 3

= Time constant utilized in the lag compensator for AT, 73 = 0 secs., ;

7 = Time constant utilized in the T lag 6

compensator for AT, 78 = 0 sees.;g ,

?

P . Pressuciter pressure (psig); i P' 2 2235 psig (Nominal RCS operating pressure):

S = laplace transform operator, sec ;

and f3(AI) is a function of the indicated difference between top and bottom detectors of the power range nuclear ton chambers; with gains to be selected based on measured instrument response during plant start-up tests such that:

(1) for q g *g between - 14% and + 10%, gf ( AI) = 0 where q j b t and 43are percent RATED THERMAL POWER in the top and bottom halves of the ; ore respectively, and a *t A is the total THERMAL POWER b

in percent of RATED THERMAL POWER; (2) far each percent that the magnituce of qt'Ub exceeds - 14%, the Delta-T trip setpoint shall be outcmatically reduced by 1.5% of its value at RATED THERMAL POWER.

(3) for each percent that the magnitude of qg- q, exceeds + 10%, the Delta-T trip setpoint shall be automatically reduced by 1.5% of its i value at RATED THERMAL POWER.

NOTE 2t The channel's maximum trip setpoint shall not exceed its computed trip point by

-more than 1.5% of instrument span.

. .i NOTE 3: OVERPOWER AT 1

1 (K

r ry u _1 i AT[("1 + 7*23I7 U)(II

I 3))

3

<4AT- K5 ((II + I 5)) g(1 + 7g3)))7 , g g77(1 + 7 3I1 - 7"3 ' f 2( AI))

7 6 Where: AT = As defined in Note 1:

AT, = As defined in Note 1; 46

NOTES FOR TABLE 3-23 (Continued)

TABLE 2.2 1 (continued)

NOTE 3: OVERPOWER AT (continued) l_* 7 11 g,y3 = As defined in Note 1; i 7 71,,,1 gg 7 3) = The function generated by the rate-lag controller for T,yg dynamic compensation:

7 7 = Time constant uttitied in the rate-lag controller for T,yg.

77 : 10 secs.,

K 4

1.09; 0

K 3 1 0.02/ F for increasing average temperature and 0.0 for decreasing average temperature; I' = As defined in Note 1; (1 + 735) 1

= As defined in hote 1; (1 + 7 6S}

K 6 : 0.00068/ F for T > T" and 0.0 for T i T",

T = as defined in Note 1; I" i indicated Tava at RATED THERMAL POWER (Calibration temperature for ATinstrumentation. 574.2 r);

5 = as defined in Note 1; f =0forallAl; 2

NOTE 4: The channel's maximum trip setpoint shall not exceed its computed trip point by more than 1.4% Delta-T span.

7. As noted in Table 2.2-1 Note 3 of Plant Technical Specifications, see above.

8. As noted in Table 3.3-3 Item 1 of Plant Technical Specifications item f; Trip Setpoint 1 A function defined as follows: a Delta-P corresponding to 40% Steam Ficw at 0% Load increastng Itnearly from 20% load to a value corresponding to 120% Steam flow at full load.

Allowable Value A function defined as follows: a Delta-P corre ponding to 42.6% Steam Flow at 0% Load increasing Itnearly from 20% load to a value corresponding to 122.6% Steam Flow at full load.

9. [ )+a,c

10. Included in [ ]+a,c

11. Not in Westinghouse Scope,

12. As noted in Item 7b & c of Table 3.3-3 of the Turkey Point Technical Specifications.

13. [ ]+a,c 47

o TABLE 3-24 OVFRTEMPERATURE AT CALCULATIONS The equation for - wperature AT is:

Air -

1 t-) + K (P r) f i(An) ig)(u j 7% s AT, ((3 - r,(l, , ,41

7,,U)(it ) 3 K r;minal) = 1.0950 Technical Specification value w K m . ;) =( ]+a,e K

2 = 0.0107'0F Kt = 0.00 4'53/ psi ATo - vessel 47 = 56.1 F Al Jain = 1.5 FP Al/%Al Reference notes to Table 3-23 for a complete listing of term:.

Delta T =

~

Delta T span = ( ]4a.c Proces: Measurement Accuracy Delta-T

( )+a,c Delta I PMA 1

~

4 4, C PMA 2

+a c Tavg ( )+a,c Pressure Channel Uncertainties

~

Pressure Gain -

Pressure SCA 6 Pressure SMTE =

Pressure STE =

Pressure 50 =

48 1

4 h

TABLE 3 24 OVERTEMPERATURE AT CALCULATIONS (Continted)

Total Allowance =

+ 8, C

= 7.2% AT span 4

49 en.,,,, ,, , ,. . - . . - - . .c - . . , -~ , . -

TABLE 3 25 OViRPOWER AT CALCULATIONS The equation for ' r AT is:

At [I' ' '111 K {(' 7U l r,tt'r 1

$ (1 ' 7 5))((1 +s 7 5)))t (1 + Tc5) 1-) . f,tal))

7 (1 + 7 5)]tIl

7 5)) : 41, (r, 3 2 3 7 K4 (nominal) 1.09 Technical Specification value K4 (max) -[ pa,c K

5 - 0.02/ 0F K

6 - 0.00068/ 0F ATo - vessel AT - 56.1 0F f-2 - O for all Al Reference nctes to Table 3 23 for a complete listing of terms.

Proce'ss Measurement Accuracy Tavg - (

)+a c ,

l Total Allowance -

r- -

+a,c l l

= 5.3% span 50 l

i TABLE 3 26 STEAM GENERATOR LEVEL DENSITY VARIATIONS Because of density variations with load, it is impossible without some form of compensation to have the same accuracy under all load conditions. The recommended calibration point is at 50% power conditions. Approximate errors at 0% and 100% water level readings and also for nominal trip points of 10% and 70% level are listed below for a typical 50% power condition calibration. This is a general case and will change somewhat from plant to plant. These errors are only '

from density changes and do not reflect channel accuracies, trip accuracies or indicated accuracies which have been defined as AP measurementsonly.II)

INDICATED LEVEL (50% Power Calibration) 0% 10% 70% 100%

Actual level --

-+a,c 0% Power Actual level 100% Power (1) Miller, R. B., " Accuracy Analysis for Protection / Safeguards and Selected Control Channels", WCAP 8108 (Proprietary), March 1973. l l

l 51 1

TABLE 3 27 AP MEASUREMENTS EXPRESSED IN FLOW UNITS The AP accuracy expressed as percent of span of the transmitter applies throughout the meastired span, i.e., i 1.5% of 100 inches AP =

i 1.5 inches anywhere in the span. Because F2 = f(AP) the same cannot be said for flow accuracies. When it is more convenient to express the accuracy of a transmitter in flow terms, the followirg method is used:

F N = APy where N = nominal flow 2FuaFy = BAPy BAP N thus aF Eq. 3 28.1 N = 2F N Error at a point (not in percent) is:

aF N BAP SAPy

= N = Eq. 3-28.2 FN 2(F)N 2APN and AP N (FN)2 where max = maximum flow Eq. 3-28.3 AP max (Imax) and the transmitter AP error is:

(APBAPy )(100) - % error in Full Scale AP Eq. (%3-28.4 FS AP) max i

l 52 i

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

. _ . - - _ - - . _ _ . - = _ _ _ . _ _ . _ - .

therefore:

BFy , (AP,,x) (percent 100 error (FS AP)) percent error (FSAP) F fy --

-2 m )2 2(APmax) (2) (100) F N

FN F

max Error in flow units is: Eq. 3 28.5 i

_2 n (

SFy - (FN )(PU }) x Eq. 3 28.6 (2) (100) F N

Error in percent nominal flow is:

- _g i 0F '"

N )(100) . Eq. 3 28.7 :

2 FN _N_F Error in percent full span is:

-2 SF N y , (I )(percent error (FS AP))

N F g

F max (Fmax) (2) (100) F N

percent error (FS AP) F 2

max )

FN Eq. 3 28.8 Equation 3 28.8 is used to express errors in percent full span in this document.

53

1-4.0 TECHNI. cal SPECIFICATION USAGE 1

, 4.1 G!RRENT USE The Standard Technical Specifications (STS) as used for Westinghouse j type plant designs (see NUREG-0452 Revision 4) utilizes a two column

! format for the RPS and ESF system. This format recognizes that the

[ setpoint channel breakdown, as presented in Figure 41, allows for a l

1 certain amount of rack drift. The original intent was to reduce the number of reporting events in-the area of instrumentation setpoint I

dri f t . It appears that this goal was achieved. However, it does not

--recognize how setpoint calibrations and verifications are performed in the plant. In fact, this.two column approach forces the plant to take j' a double penalty in the area of calibration error. As noted in j figure 4 1, the plant must allow for calibration error below the STS

( Trip Setpoint, in addition to the allowance assumed in the various accident analyses, if full utilization of the rack drift is wanted.

This is due, as noted in 2.2, to the fact that calibration error 4

cannot be distinguished from rack drift after an initial calibration.

Thus, the plant is left with two choices; 1) to assume a rack drift value less than that allowed for in the analyses (actual RD = assumed RD RCA) or, 2) penalize the operation of the plant (and increasing the possibili_ty of a spurious trip) by lowering-the nominal trip setpoint into the operating margin.

The use of the summation technique described in Section 2 of this report allows for a natural- extension of the two column approach.

This extension recognizes the calibration / verification techniques used in tha plants and allows for a more flexible approach in determining reportability. Also of significant benefit to the plant is the i

. incorporation of sensor drift parameters on an 18 month basis (or more oftenifnecessary)'.

s

(

54

_ ~_ . - - _ , _ _ _ . . ,__,_ ._ _ _._ _ __ _ . _ ___ _ _ _ _ _ _

I 1 l j.

4.2 WESTINGHOUSE SETPOINT METHODOLOGY FOR STS SETPolNTS 4-Recognizing that the plant experiences both rack and sensor drift, a '

different approach to Technical Specification setpoints may be used, i

] This revised methodology accounts for two additional factors seen in the plant during periodic surveillance, 1) interactive effects for

) both sensors and rack and, 2) sensor drift effects.

i 4.2.1 RACK ALLOWANCE Inte'ractive effects will be covered first. When an instrument

. technician looks for rack drift, more than that is seen if "as l

left/as found" data is not used. This interaction has been noted-

several times and is treated in Equations 2.1 and 3.1 by the arithmetic summation of the rack effects, RD, RMTE, RCSA, and RCA; L and the sensor effects, SD, SMTE and SCA. To provide a conservative

- trigger value", the difference between the STS trip setpoint and the L STS allowtble value is determined by two methods. The first is simply tho. values used in the CSA calculation,

~

T; - (RCA + RMTE + RCSA + RD) _

(Eq.4.1) !

The-second extracts these values from the calculations'and compares the remaining values against the total allowance:

-T2 TA - ((A) + (S)2)l/2 - EA (Eq.4.2) where:

~T2 - Rack trigger value .

A' =.(PMA)2 + (PEA)2 + (SPE)2'+ (STE)2 + (RTE)2 .

S -(SCA'+ SMTE + SD)

EA' TA and all other parameters are as defined for Equation 2.1.

i.

I L 55

The smaller of the trigger values should be used for comparison with the "as measured' (RCA + RMTE + RCSA + RD) value. As long as the "as measured" value is smaller, the channel is within the accuracy allowance. If the "as measured" value exceeds the " trigger value",

the acM1 number should be used in the calculation described in Section 4.2.3. This means that all the instrument technician has to do during the periodic surveillance is determine the value of the bistable trip setpoint, verify that it is less than the STS Allowable Value, and does not have to account for any additional effects. The same approach is used for the sensor, i.e., the "as measured" value is used when required. Tables 4-1 and 4 2 show the current STS setpoint philosophy (NUREG 0452, Revision 4) and the Westinghouse rack allowance for Turkey Point Units 3 & 4 (31 day surveillance for analog and 92 day surveillance for digital). A comparison of the differences between the Safety Analysis Limits and Allowable Values will show the relative gain of the Westinghouse version.

4.2.2 INCLUSION OF "AS MEASVRED" SENSOR ALLOWANCE If the approach used was a straight arithmetic sum, sensor allowances for drift would also be straight forward, i.e., a three column setpoint methodology. However, the use of the Westinghouse methodology requires a somewhat more complicated approach. The methodology is based on the use of Equation 4.3, and demonstrated in Section 4.2.3, Implementation.

TA 1 {A)l/2 + R + S + EA (Eq. 4.3) where:

R = the 'as measured rack value" (RCA + RMTE + RCSA + RD)

S - the "as measured sensor value" (SCA + SMTE + SD) all other parameters are as defined in Equation 4.2.

56

l I

Equation 4.3 can be reduced further, for use in the STS to:

TA 2 Z + R + S (Eq. 4.4) where:

Z - (A)l/2 + EA Equation 4.3 would be used in two instances, 1) when the ".~,

measured" rack setpoint value exceeds the rack ' trigger value' as defined by the STS Allowable Value, and, 2) when determining that the "as measured" sensor value is within acceptable values as utilized in the various Safety Analyses and verified every 18 months.

4.2.3 IMPLEMENTATION OF THE WESTINGHOUSE SETPOINT METHODOLOGY Implementation of this methodology is reasonably straight forward, Appendix A provides the text and tables for use at Turkey Point. An example of how the specification would be used for the Pressurizer Pressure Low reactor trip is as follows.

For the periodic surveillance, as required by Table 4.3-1 of NUREG 0452, Revision 4, a functional test would be performed on the channels of this trip function. During this test the bistable trip setpoint would be determined for each channel. If the "as measured" bistable trip setpoint error was found to be less than or equal to that required by the Allowable Value, no action would be necessary by the plant staff. The Allowable Value is determined by Equation 4.2 as follows:

T2 - TA - ((A) + (S)2)1/2 - EA 57

1 1

l where:

TA = 4.5%

+a,c A = .

5 =

EA =

T2 l

l However, since only Ti={ ]+a,c is assumed for T in the various analyses, that value will be used as the " trigger value".

The lowest of two values is used for the " trigger value"; either the value for T asrsted in the analyses or the value calculated by Equation 4.2.

Now assume that one bistable has " drifted" mo: e than that allowed by the STS for periodic survei. lance. According to ACTION statement b.1, the olant staff must verify that Equation 2.2 1 is met. Going to Table 2.2-1, the following values are noted: Z = 1.12 and the Total Allowance is (TA) = 4.5. Assume that the "as measured" rack setpoint value is 2.75% low and the "as measured" sensor value is 1.3%. Equation 2.2 1 looks like:

TA 2 Z + R + S 1.12 + 2.75 + 1.3 1 4.5 5.2 > 4.5 As can be.seen, 5.2% is not less than 4.5% thus, the plant staff must follow ACTION statement b.2 (declare channel inoperable and place in the" tripped" condition). It should be noted.that if the plant staff had not measured the sensor drift, but instead used the value of S in Table 2.21 then the sum of Z + R + 5 would also be greater than 4.5%. In fact, anytime the "as measured" value for rack drift is l

58 I

greater than T (the " trigger value") and there is less than 1.0%

margin, use of S in Table 2.2-1 will result in the sum of Z + R + S being greater than TA and result in the determination that the channel is inoperable.

If the sum of R + S was about 0.75% less, e.g., R - 2.0%, S - 1.3%

thus, R + S = 3.3%, then the sum of Z + R + 5 would be less than 4.5%. Under this condition, the plant staff would recalibrate the instrumentation, as good engineering practice suggests, but the channel is considered operable, even though the " trigger value" is exceeded, because Equation 2.2-1 was satisfied.

In the determination of T for a function with multiple channel inputs there is a slight disagreement between Westinghouse proposed methodology and NRC approved methodology. Westinghouse believes that T should be either:

Ti - (RCAi + RMTE3 + RCSAi + RD}) +

(RCA2 + RMTE2 + RCSA2 + RD 2 ) (Eq. 4.5) or T2 - TA - {A + (Si )2 + ($2 )2)l/2 - EA (Eq. 4.6) where the subscript I and 2 denote channels 1 and 2, and the value of T used is whichever is smaller.

The NRC in turn has approved a method of determining T for a multiple channel input function as follows, either:

T3 = ((RCAi + RMTEi + RCSA1 + RD 1

)2 ,

(RCA2 + RMTE2 + RCSA2 2 + RD ) )l/ (Eq. 4.7) or Equation 4.6 as described above.

59

.. --_--_-_-_-_------------------a

i ,

Tl. Again the value of T used is whichever is smaller. This method is described in NUREG 0717 Supplement 4, dated August 1982.

The complete set of calculations follows for High Steam Flow to

[ demonstrate this aspect (values noted are from Table 317),

s A-

+a,c

- TA -

A =

=

Si

, Sg =

T 2 = TA BIAS - (A + (S)2)l/2

+a,c g T2 *I- 3 T3 '- ((RCAS + RMTES + RCSA 3 + RD 3 )2 +(RCAT + RMTET + RCSAT + RDr)2)l/2 g .T 3 .[ pa,c The value of.T used is. based on Equation 4.7 (T3 ). In this '

document Equations 4.6.and 4.7, whichever results in the smaller value, is used for multiple channel input functions to remain consistent with current NRC approved methodologies. Table'4-1 notes the values of TA, A, S T, and Z for all protection functions and is utilized in the determination of the Allowable Values noted in.

F Appendix A.

Table _4.31 also requires that a calibration be perfened every

refueling!(approximately18 months). To ~ satisfy this requirement, the plant staff would determine the bistable trip setpoint (thus, determining the "as measured" rack value at that time)_and the sensor "as measured" value. Taking-these two "as measured" values and using'-

L Equation 2.2 1 again the plant-staff can determine that the-tested channel is in fact within the-Safety Analysis allowance.

60

4.3 (DHCLUS!QS Using the above methodology, the plant gains added operational flexibility and yet remains within the allowances accounted for in the various accident analyses. In addition, the methodology allows fa a sensor drift factor and an increased rack drift factor. These two gains should significantly reduce the problems associated with channel drift and thus, decrease the number of instances a channel is determined to be inoperable while allowing plant operation ir a safe manner.

i 61

d a

TABLE 4-1 I

EXAMPLES OF CURRENT STS SETPOINT PHILOSOPHY l

Power Range Pressurizer Neutron Flux - Hiah Pressure Low 1

Safety Analysis Limit 118% RTP 1790 psig l

STS Allowable Value 110% RTP 1825 psig STS Trip Setpoint 109% RTP 1835 psig TABLE 4 2 EXAMPLES OF WESTINGHOUSE STS RACK ALLOWANCE Powc- Range Pressurizer Neutron Flux - Hiah Ettssure - Low Safety Analysis Limit 118% RTP 1790 psig STS Allowable Value 112% RTP 1817 psig (TriggerValue)

'STS Trip Setpoint 109% RTP 1835 psig 62

i i

Safety Analysis Limit i

( Process Measurement Accuracy j..........

( Primary Element Accuracy l..........

( ' Sensor Calibration Accuracy j..........

i ( Sensor Measurement & Test Equ'.pment l.......... l

( Sensor Pressure Effects l..........

l

( Sensor Temperature Effects l..........

( Sensor trift 5..........

( Environmental Allowance i.........

( Rack Temperature Effects j..........

( Rack Comparator Setting Accuracy l..........

( Rack Calibration Accuracy l..........

( Rack Measurement & Test Equipment STS Allowable Value l--------

( Ra:k Drift STS Trip Setpoint Actualftalibration Setpoint Figure 4-1 WUREG-0452 Rev. 4 Setpaint Error Breakdown -

(Analog Process Racks) m

Safety Analysis Limit j..........

( Process Measurement Accuracy j..........

( Pric' ~'ement Accuracy i.......

( Sensor Calibration Accuracy

( Sensor Measurement & Test Equipment l..........

( Sensor Pressure Effects l..........

( Sensor Temperature Effects

( Sensor Drift i..........

( Environmental Allowance l...........

( Rack Temperature Effects STS Allowable Value l.--.......

( Rack Comparator Setting Accuracy I...........

( Rack Calibration Accuracy j..........

( Rack Heasurement & Test Equipment j.........

( Rack Drift STS Trip Setpoint Figure 4-2 Westinghouse STS Setpoint Error Breakdown (Analog Process Racks) 64

.. a s'

T ARL E 4 3 bE$11NGH0J$[ PR0f ttil0N SY$1[M $f $ $l100lk TLMEY PolWT Unit $ 3 & 4 101At AL LNANCE (7) (7) (7) (7) I N$1RtN PR0fttil0N CHANNfL (TA) (72 [A.) (1) ($) (2) (1) (3) E 7 ) . _.. E f. ) $$8W

- a+a,c PO.!LR RANGE, NEUIRON ILUX HIGH $EIPolWi 7.5 0.0 2.5 4.56 120% Rif PWER RANGL, NEUTRON FLUX LOW $tiPOINT 8.3 0.0 2.5 4.56 120% RTP-

!NilRMEDI ATE RANGE, NEUIRON ILUX 13.5 0.0 5.0 8.41 120% tir.

$0URCE RANGE, NEUTRON FLUX 13.9 0.0 3.9 10.01 1 E*6 CPS OVERTLMPERATURE DillA f 7.2 2.5 1.5 4.82 (5)

OVERPOWER DELTA f 5.3 2.0 1.4 3.09 (6)

PRES $URl![R PRESSURE

LOW 4.5 1.4 1.9 1.12 1000 P51 p PREt$URIZIR PRE $$URL a HlCH 5.5 1.4 1.9 1.12 1000 PSI PFLOSURil(R WAf(R (( VEL . HlCh 8.0 4.0 0.2 6.76 100% $PA (0$$ OF FLOW 4.6 0.8 1.1 2.65 120% FL STEAM GENERATOR WAftR LEVEL LOW LW 5.0 1.9 1.9 2.33 100% $PA

$1EAM CENERATOR WATER L[ VEL LEM 5.0 1.9 1.9 2.33 100% $PA

. $fEAM/!EED FLEW Mi$ MATCH 20.0 1.7*2.9*2.8 3. 7. 3.67 120% ft UNDERVOLTAct 4.16KV BUS 20.0 0.0 3.1 1.12 1040 VAC UNDIRf R(OLE NCY 16.4 0,0 2.5 0.50 7 H2 TURBlWE ikiP AU10 $10P OIL PRES $URE 8.6 0.0 3.8 1.0 58PSIG!

CONI AINMENT PRE $$URE HIGH, $1 2.0 0.0 1.5 0.2 100 PSIG PRESSURl!ER PRESSURE LOW, $AIETY INJECil0N 13.0 1.4 1.9 - B.42 1000 PSI Dnif. PRES $URE BETWEfN $1H HEADER & $1M LINES HlGH 4.7 4.6 1.0 1.57 1400 PSI HIGH STEAM LINE FLOW $1, $1EAM LINE ISOLAll0N 16.7 1.7*2.2 2.2 2.86 120% FL STEAM LINE PRESSURE

LOW $1, $ TEAM LINE l$0LAfl0N 13.0 2.3 1.9 1.16 1400 PEI CONTAINMENT PRES $URE HIGH'HlGH, $ PRAY 10.0 0.0 1,4 1.60 100 PSIG CONTAINMENT RAD 10ACT!Vl1Y HIGH PAR 1!CLAATE CTM I$L 13.0 - 0.0 7.3 0.50 999990 C favo LOW'LN, $1, STE AM LINE ISOLA 110N 4.0 1.0 0.7 2.00 75'T CONTAINMENT RAD 10ACilVITY HIGH CA$EW$, CIM ISL 8.0 0.0 7.3 0.50 49990 (P 4 '

l ... 0;aRADED VOLTACE AND INVER$E TIME DEGRADE 0 (12) ~ ~ (12) (12) (12) (12).

VOLIAGE FOR ALL 480VAC LOAD CENTER $

65 l

=

) INeut5

N1 ggs jpg gtg Atto,jngt( p,A y l4JM iL!!%tliL_. YMki _ - - YRL'L-i?)

- - *e.<

1p?% tir 112.0% LIP

?$% tit ?B.U% RTP

?$% tip 31% 6tP 1I*$ CPS 1.4 i+5 CPS fvwCiltw (B) fuNCilON (B)

+1.5% Di !JAN IUNCfl(W (B) FUNCIlON (B)

1.4% Di !#AN 183$ PS!G 1817 Pfl0 23t5 051G P403 PsiG 9?% SPAN 9? 2% LLAN 90% $0AN (2.7% LPAN ik% SPAN 13.7% SPAN B% $PAIJ 13.2% ttAN 20% FLOW (10) 23,74 (103 (10) 70% BUS VAC 6'/1 0U5 V AC 56.1 H2 $$.9 H2 45 0510 43 PSIG 4 PSIG 5.5 P51C 1730 PSIG 1712 PSIG 100 P510 114 05tG

! 40% ILOW (11) 4?.6% fl0W (11)

. 6)( 051G $M PSIG 20 PSIG 21.4 PstG

'M 6.1 (*5 COM 6.8 (*$ CPM ,

543"I 54?.5*f 1

3.? (*4 Citt 3.5 (*4 CIH b$

(i?> (in - ~ APERTURE t, CARD

l. '

Also AvaliaW' On Aperture Card 90lzz40121 -0? .

NOTES FOR TABLE 4 3 (1) A - (PMA)2 + (PEA)2 + (SPE)2 + (STE)2 + (RTE)2 (2) S - SCA + SMTE + SD (3) T1 RCA + RMTE + RCSA + RD ,

T 2 TA - {A + (Si )2 + (Sp)2)l/2 EA T3 - ((RCA3 + RMTEi + RCSA3 3+ RD )2 +

(RCA2 + RMTE2 + RCSA2 + RDg)2)l/2 T - minimum of Ti , T2 or T3 (4) Z - (A)l/2 + EA (5) Parame m inn Tavg 750F Pressure 1000 PSIG Flux 120% RTP AT 750F Al i 100% 41 (6) Egtag11r Egg Tavg 750F AT 750F (7) All values in percent Span 66

NOTES FOR TABLE 4 3 (Continued)

(8) As noted in Notes 1, 2, 3 and 4 of Table 2.2-1 of the Turkey Doint Technical Specifications shown below T AtlLE 2.21 T Alttt NotAtloh RfAtt0R TRIP SY5t[M lh$tRUMEhtAT10N tRlP 5ttP0tht$

h0tt 1: OV(Rt(MP(RAtutt At At( (1'l *+ 'lU 1 f 5) )((1 + 7 5;) : At, (K fl *+774U K,( (1 1

T>) + K3(P P') - f 3(AI))

g 3 3

3

5) )(it(1 + 7 bI) 6 Where: At . Measured At by RfD instrumentation; 17i 1

= Lead / Leg compensator on measured Af; g,73 73.73 . Time constants ut titted in the lag compensator f or At; 7 g. a secs. , 7,. 3 secs. ;

1

( g , y [) = the function generated by the rate lag controller for tavg dynamit compensat ton; Ai, : Indicated Delta t at RAtt0 THtRMAL P0wtR:

K; i 1.095; K

2

0.0107/'F; i+71 4 g,7$ = the function generated by the lead lag controller for f avg dynamic compensation; 7 ,7 = time constants utilized in the lead lag 4 3 controller for favg, 74 = 25 sees.. Tg . 3 secs.;

i e Average temperature 'F; 1

g,7g

Lag compensator on measured 13 ,9; t'

1574.2'F(hominalT,yg at RATED THERMAL POVER)

K 3

1 0.000453/psig; .

7 3

= time constant utittred in the lag compensator for AT. 73 O sees.

7 6 = time constant uttitred in the t,yg lag compensator for AT, 75 O sees.:

67

l

\

l NOTES FOR TABLE 4 3 (Continued)

TABLE 2.2 1 (continued)

NOTC 1: Ov[RT[MPIRATURt AT (cutinued)

P a Pressuriger pressure (psig);

P' : 2235 psig, (hominal RC5 crerating pressuu):

^

$ = laplace transform operator, sec ;

and fg(AI) is a function of the indicated dif ference, oetween top and bottom detectors of the power range nuclear ion chant;ers: with gains to be selected based on measured instrument response during plant start up tests such that s (1) f" Qt"Ob between - 14% and + 10%, gf (AI) = 0 where o g and abare percent Raft 0 THERMAL POWER in the top and bot'om helves of the core respectively, and a *t U is the total THERMAL PfNfR b

in percent of RAftD THERMAL POWER; (2) for each percent that the magnitude 01 4 *O exceeds - 14%, the 1 b Delta T trip setpoint shall be automatically reduced by 1.5% of its value at RAT [D TH[RMAL POWER.

(3) for each percent that the magnitude of at ' 'b exceeds + 10%, the Delta-T trip setpoint shall be automatically reduced by 1.5% of its value at RAT [D THERMAL POWER.

NOT[ 2: The channel's maximum trip setpoint shall not exceed its (.omputed trip point by more than 1.5% of instrument span.

NOTE 3: OvtRPOWER DELTA-T AT[ l

)( l ) : AT, (K 4 K (( [7 3 )( , ))T-K,(T[g[ T") - f,( At ))

Where: AT As defined in Note 1:

A T, . As defined in Note 1:

1+71 3

= As defined in Note 1; g7g 2

68

i NOTES FOR TABLE 4 3 (Continued)

IABLt 2.2-1 (cont inued)

[g

The function generated by the rate-lag controller for 7,yg dynamic comoensat ion, 7

7

Time constant utilized in the rate-lag coetroller for T,yg, 77 10 sect.

K 4

1.09; K

g 3 0.02/'r for increasing averape temperature and 0.0 for decreasing average temperature:

1 (1 + 735) e As defined in hote 1; 1

(1 + 7 65) = As defined in hote 1; K

6 1 0.00068/'F for i > 1" and 0.0 for i i 1";

I = As defined in hote 1; 1"

= Indicated I,yg at RAT [D THERMAL POWIR (Calibrat ton temperature for At instrumentation, 3 574.z r);

s = As defined in hote li f

g = 0 for all At; NOTI 4: The channel's maximum trip setpoint shall not exceed its computed trip point by more than 1.4% Delta T span, (9) This column provides the maximum value for a bistable assuming that the transmitter is not evaluated and the values for S, Z and TA from this table are used in the following equation: R = TA - Z S.

This implies that the transmitter is assumed to be at it's maximum allowed calibration and drift deviation in the non-conservative direction. With a bistable's Trip Setpoint found in excess of the value noted in this column, it is possible (but not known absolutely) that a channel would be considered inoperable. This must be tempered by the transmitter assumption noted above, i.e.,

the transmitter is assumed to be at it's worst acceptable condition.

69

NOTES FOR TABLE 4 3 (Continued)

(10) As noted in item 12 of Table 2.21 of the Turkey Point Technical Specifications; Trip $stpoint Feed Flow 120% below $ team Flow Allowable Value Fted Flow i 23.9% below $ team Flow _.

(11) As noted in item 1 of Table 3.3 3 item f, of the Turkey Point Technical Specifications trip $ctpoint i A function defined at follows: A Delta-P correspond 6ng to 40% Steam Flow at 0% load increasing linearly from 20%

load to a value corresponding to 120%

Steam Flow at full load.

Allowable Value i A function defined at follows: A Delta P corresponding to 42,0% Steam Flow at 0% load increasing linearly from 20%

load to a value corresponding to 122.0%

Steam Flow at full load.

(12) As noted in Item 7b & c of Table 3.3 3 of the Turkey Point Technical Specifications. .

70

B MW APPENDIX A TURKEY POINT UNITS 3 & 4 SETPOINT TECHNICAL SPECIFICATIONS 71

l APPENDIX A 1AJETY LIMITS _MD LIMITING SAFETY SYSTEM SETTINGS 2 2 LIMITING SAFETY SYSTEM SETTINGS REACTOR TRIP SYSTEM INSTRUMENTATION SETPOINTS 2.2.1 The Reactor Trip System Instrumentation and Interlock Setpoints shall be set consistent with the Trip Setpoint values shown in Table 2.2-1.

APPLICABILITY: As shown for each channel in Table 3.3-1.

ET.lM1

a. Sith a Reactor Trip System Instrumentation or Interlock Setpoint less conservative than the value shown in the Trip Setpoint column but more conservative than the value shown in the Allowable Value column of Table 2.2-1, adjust the setpoint consistent with the Trip setpoint value within permissible calibration tolerance.

b. With the Reactor Trip System Instrumentation or Interlock Setpoint less conservative than the value shown in the Allowable Value column of Table 2.2-1, either:

1. Adjust the Setpoint consistent with the Trip Setpoint value of Table 2.21 and determine within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months that Equation 2.2 1 was satisfied for the affected channel or

2. Declare the channel inoperable and apply the applicable ACTION statement requirement of Specification 3.3-1 until the channel is restored to OPERABLE status with its setpoint adjusted consistent with the Trip Setpoint value.

EQUATION 2.2-1 2 + R + S 1 TA where:

2 -

The value for column Z of Table 2.2-1 for the affected channel, R = The "as measured" value (in percent span) of rack error for the affected channel, S -

Either the "as measured" value (in percent span) of the sensor error, or the value of Column S (Sensor Error) of Table 2.2-1 for the affected channel, and TA = The value for Column TA (Total Allowance in percent of span) of Table 2.2-1 for the affected channel.

TURKEY POINT - UNITS 3 & 4 2-3

f APPEWDlx A TABLt 2.2 1 react 0R 1 RIP $t$ TIM IW$'iRWik1Afl0N TRIP SE1Polkt$

1 Total l

I Allowance lersor Orlft Fune t t onel Uni t (TA) (f) (1) Trio tetr W t Allowable Value

1. Mamel Reactor irlp AA kA bA hA kA

2. Power Range, heutrcn Flux,

s. High $etpoint 7.5 4.56 0.0 g 109% RTP ** g 112.0% RTP "

b. Low $*tpoint 8.3 4.56 0.0 g 25% RTP " 3 28.0% RTP "

3. Intermediate Range, heutron Flun 13.5 8.41 0.0 3 25% aTP a 31% RTP "

4. Source Range, Woutron Flux 5 13.9 10.01 0.0 3 10 CP$ 3 1.6 a 105gpg

5. Overtenperature Dette T 7.2 4.62 2.5 # see Note i see Note 2

6. Overpower Dette 1 5.3 3.09 2.0 see Note 3 See Note 4

7. Pressuriter Pressure

Low 4.5 1.12 1.4 g 1835 P810 1 1817 P$tG

8. Pressurlaer Pressure

Migh 5.5 1.12 1.4 g 2385 P810 3 2403 P$10 9 Pressurlier Water Level High 8.0 6.76 4.0 g 92.2% of instrunent 3 92% of instrunent Span Span.

10. Reactor Coolant Flow . Low 4.6 2.65 0.8 3 90% of Loop g 88.7% of Loop Design Flow

Design Flow *

11. Steam Generator Water Levet Low Low $0 2.33 1.9 1 15% of narrow range 1 13.2% of narrow instrutent span range instrument span Loop Design Flow a 89,500 g;n

- RTP a RAftD THERKAL POWER e 2.0% Span for Det'n T (RfDs) and 0.5% for Pressuriser Pressure TURKEY POINT + UN!!$ 3 & 4 24

Aft!NDlK A 1

1ABLE 2.21 (conttrued)

REACTOR TRIP $YlitM IktTRWWTATION TRIP Bil?Olkit total Allowance sersor Orlf t h nettonet Unit (TA) (!) ($) Trio Set mtnt Attowable Velve

12. SteenVFeedwater Flow Mismatch Cotreident with 20.0 3.67 7.3 N Feed flow 3 20% tetow Feed Flow 3 23.9% tetow Steam Flow $ team flow Steam Gereretor Water Level Low 3.0 2.33 1.9 > 15% of narrow range = 13.2% of narrow range Instrtment span Instrtment span

13. Undervoltage RCP 20.0 1.12 0.0 1 70% bus voltese g 69% tua voltese

14. UnderfreqJency RCP 16.4 0.50 0.0 .> 56.1 Ha g 55.9 N:

15. Tsrbine irlp Auto Stop Ott Pressure 8.6 1.0 0.0 t 45 PS10 1 43 PSIG furbine Stop Velve Closure kA NA NA Fully Closed *" Fully Closed "*

16. Safety injection tryut from EtF NA kA kA NA NA

17. Reactor Trip System Interlocks

a. Intermedlete Range Neuteen Flux, P 6 ,gg NA NA kA Nominal 1 x 10 ante 1 6.0 x 10,gg ants

"* Limit switch is set when turbine Stop Velves are fully closed.

H 1.7% $ pen for Steam Line Flow, 2.9% Span for Feedwater Flow and 2.8% Span for Steam Line Pressure.

TURKEY POINT UNIf$ 3 & 4 25

APPENDIX A TABLE 2.21 (contirued)

REACTOR TRIP $YSTEM INSTR (HENTAfl0N TRIP $ETPolNTS Total Allowance Sensor Drifi Functionet Unit (tA) (r) (s) ;'n setroint A t t evat:le Vet ue

17. i.e4*or Trip Syst M Interlocks (conti aed)

b. Low Power Reactor Trips Block, P 7

~

1) P 10 trput NA kA kA Nominst 10% RTP " 3 13.0% RTP **

2) Turbine First Stege NA NA NA Nominal 10% Turbine 5 13.(r1 Turbine Pressure Power Power

c. Power Range Neutron Flux.P+8 NA NA NA Nominal 45% RTP ** 5 48.0% RTP **

d. Power Range Neutron Flux, P+10 NA NA NA Nominal 10% RTP ** 1 7.0% RTP **

18. Reactor Coolant Ptmp WA NA NA NA M Breaker Positico Trip

19. Reactor Trip Breakers NA NA NA NA kA

20. Automatic Trip and Interlock NA NA NA NA NA Logic

- RTP = RATED Tr;RW'. POWER TURKEY POINT + UNITS 3 & 4 26

APPENDIX A

~

TABLE 2..?-l (continued)

REACTOR TRIP SYSTEM INSTl;UMENTAT!M '41P SETPOINTS TABLE NOTATID, NOTE 1: OVERTEMPERATURE AT .

AT(( 1,p({;-,'7,3)): AT,{K3 - K,{('} , 7 ,y)(t({ 7 $))} - T') + K 3 g (P - P') - f (4I))

'Where:.AT = Me m red AT by RTD Instrumentation; 1+7S = lead / Lag compensator on measured AT; 1+rfS 71,72 = Time ~ constants utilized in the lag compensator for AT; 71= 8 secs., 72= 3 secs.;

(1y77y - The function generatef by the rate-lag controller for T avg dynamic compensation; AT o s Indicated AT at RATED THERMAL POWER; K

1 1 . 095;

0.0107/ 0F;

^

'K 2 4

f++#f 5

= The function generated by the lead-lag .

controller for T avg dynamic compensation; ,

74 '75 = Time constants utilized in the lead-lag -

controller for Tavg' T4 = 25 secs.,

75 = 3 secs.;

T ..= Average temperatureOF; I I 1 + -' 76 s = Lag c mpensator.on measured T avg i T' 0 5 574.2 F (Nominal T ayg at. RATED THERMAL POWER)

L K-3 2 0.000453/psig;

= Time constant utilized in the-lag compensator-73 for AT, 73 = 0 secs.;

TURKEY POINT - UNITS 3 & 4 2-7

,+

APPENDIX A-TABLE 2.2-l'(continued)

REACTOR TRIP SYSTEM INSTRUMENTATION TRIP SETPOINTS TABLE NOTATION NOTE i: OVERTEMPERATURE AT (continued) 76 - Time constant utilized in the a lag compensator for AT, 76 O secs.vg ;

P - Pressurizer pressure (psig); -

P! 2 2235 psig, (Nominal RCS operating pressure); o S - Laplace transform operator, see'I; and-f (AI) is~a function of the indicated difference between top

- and bo}ttom _ detectors of the_ power range nuclear ion chambers; with

_ gains to be selected: based on measured instrument response during plant

.startup tests such that:

3 (1) for qt " 9b between 14% and + 10%, fi(AI) - O q

' where qt and qb are percent RATED THERRAL POWER in the ;

top and bottom halves of the core respectively, and qt + l gh is the total-THERMAL POWER in percent of RATED-

TRERMAL POWER; (2)- for each 9 rcent that the magnitude of qt

9b exceeds

- 14%,' the Delta-T trip setpoint shall be automatically ,

reduced by 1.5% of its value at RATED THERMAL DOWER, t

-(3)--

~

for each percent that the' magnitude of qt

Ab exceeds

+ -10%, Jthe Delta-T trip setpoint :shall' be automatically reduced by 1.5% ofLits valuelat RATED THERMAL POWER. I

< NOTE 2L The-channel!s maximum-trip setpoint shall not exceed its computed trip _

, point by more: than 1.5% of. instrument span.

L L

TURKEY POINT UNITS.3 & 4 2-8

+ - < m w,ar+, e < ,a r w .-, ,,r, , , e w w

. ._ . - . _ . - _ _ . . _ . . _ _ . _ ._ m.. . _

i APPENDIX;A TABi.E 2.2 (continued) i REACTOR TRIP SYSTEM INSTRUMENTATION TRIP SETPOINTS TABLE NOTATION

NOTE 3: OVERPOWER AT

^

3 4 - K3 (((p7

)(

OIki+7,3 3 ki + 37 3)) : AT,(K i )(i+rs ' "6 i + r,s) " U ~ f "

t -i a

. Where: AT = As defined in Note 1; 1 + 7 fi

-}+73 - As defined in Note 1; -t 2

~1 1+733 - As defined in. Note'1; AT o - As defined in Note 1; i K.4 g 1.09;-

K5 1 0.02/ 0F for increasing average temperature and_0.0Lfor decreasing average

-temperature;-

~If S)

(1 77S) = The function generated'by the rate-lagL controller for T avg dynamic, compensation; ;

i 77- -- Time constant = utilized in the rate-lag-controller for Tavg'~77 1 10 secs.; _j

3. + 763 - As defined in Note 1; 76 - As' defined in Note 1; i

l 1

l

/

TURKEY POINT --UNITS 3 &-4 2-9

--.ra -.+-.---n,- ,- ...-w--. s - , ,,,-

(-

. APPENDIX A TABLE 2.2-1 (continued) s l REACTOR--TRIP SYSTEM INSTRUMENTATION TRIP SETPOINTS TABLE NOTATION.

NOTE 3:. -0VERPOWERAT(continued)

.K- 6 1 0.00068/0 F for T > T" and 0.0 for T-$ T";

T = As defined in Note 1; T" - Indicated T avg at RATED THERMAL POWER ;

(Calibration temperature for AT i

, instrumentation,-s 574.20F); .

S. - As defined in Note 1; i f 2(AI)- = 0 for-all AI.

~

NOTE 4: LThe channel's maximum-trip setpoint-shall not_ exceed its computed trip

~ point by.moreithan 1.4% AT span.

l

-l LTURKEY POINT --UNITS 3 & 4 2-10 l l

y L .

a

APPENDIX A 2.2 LIMITING SAFETY SYSTEM SETTINGS MSES 2,2.1 REACTOR TRIP SYSTEM INSTRUMENTATION SETPOINTS The Reactor Trip Setpoint Limits specified in Table 2.2-1 are the nominal values at which the Reactor trips are set for each functional unit. The Trip Setpoints have been selected to ensure that the reactor core and reactor coolant system are prevented from exceeding their safety limits during normal operation and design basis anticipated operational occurrences and to assist the Engineered Safety Features Actuation System in mitigatira the consequences of accidents. The setpoint for a reactor trip system or interlock function is unsidered to be adjusted consi'itent with the nominal value when the "as measured" setpoint in within the band allowed for calibration accuracy.

To accommodate the instrument drift that may occur between operational tests and the accuracy to which setpoints can be measured and calibrated, Allowable Values for the Reactor Trip Setpoints have been specified in Table 2.2-1. Operation with setpoints less conservative than the-Trip Setpoint but within the specified Allowable Value is acceptable since an allowance has been made in the safety analysis to accommodate this error.

An optional provision has been included for determining the OPERABILITY of a channel when its trip setpoint is found to exceed the Allowable Value.

The methodology of this option utilizes the "as measured" ("as found")

saviation from the specified calibration point for rack and sensor components, in conjunction with a statistical combination of the other uncertainties of the-instrumentation to measure the process variable, and the uncertainties-in calibrating the instrumentation. In Equation 2.2-1, Z + R + S 1 TA, the interactive effects of the errors in the rack and the sensor, and the "as measured" ("as found" - nominal) values of the errors are considered. Z, as specified in Table 2.2-1, in percent span, is the statistical' summation of errors assumed in the analysis excluding those associated with the sensor and rack drift and the accuracy of their measurement. TA or Total Allowance is the difference, in percent span, between the trip setpoint and the value used in the analysis for reactor trip.

R or Rack Error is the "as measured" ("as.found" - nominal) deviation, in percent span, for the affected channel from the specified trip setpoint. S or Sensor Drift is either the "as measured" ("as found" 4

- nominal) deviation of the sensor from its calibration point or the value specified in Table 2.2-1, in percent span, from the analysis assumptions.

Use of Equation 2.2 1 allows for a senser drift factor, an increased rack drift factor, and provides 4 threshcid value for deterrining reportability.

The methodology to derive the Trip Setpoints 4 based upon combining all of the uncertainties in the channels. Inherent to the determination of the Trip Setpoints are the magnitudes of these channel uncertainties.

l

. TURKEY POINT - UNITS 3 & 4 8 2-3 l

APPENDIX A~

2~.2 LIMITING SAFETY' SYSTEM-SETT. igg 3 BASES 2.2.1 REACTOR TRID SYSTEM INSTRUMENTATION SETPOINTS Sensors and other-instrumentation utilized in these channels are expected to be capable of operating within the allowances of these uncertainty magnitudes. Rack drift in excess of the Allowable Value exhibits the behavior.that the rack has not met its allut$nce. Being that there is-a small statistical chance that this will happen, an infrequent excessive drift is. expected.: Rack or sensor drift, in excess of the allowance that is more than occasional, may be indicative of more serious problems and should-warrant'further investigation.

i 1

l l

TURKEY POINT - UNITS 3 & 4 8 2-3 (cont'd) ,

t

APPENDIX A LiliwhG CONDITION FOR OPERATION 3.3.2 The Engineered Sa ty Feature Actuation System (ESFAS) instrumentation channels and interlocks shown in Table 3.3-2 shall be OPERABLE with their Trip Setpoints set consistent with the values shown in the Trip Setpoint column of Table 3.3-3 APPLICABillTY: As shown in Table 3.3-2.

ACTION:

a. With an ESFAS Instrumentation or Interlock Setpoint trip less conservative than the value shown in the Trip Setpoint column but more conservative than the value shown in the Allowable Value columr, of Table 3.3-3, adjust the setpoint consistent with the Trip setpoint value within permissible calibration tolerance.

b. With an ESFAS Instrumentation or Interlock Setpoint less conservative than the value shown in the Allowable Value column of Table 3.3-3, either:

1. Adjust the Setpoint consistent with the Trip Setpoint value of Table 3.3-3 and determine within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months that Equation 2.2-1 was satisfied for the affected channel, or

2. Declare the channel inoperable and apply the applicable ACTION statement requirements of Table 3.3-2 until the channel is restored to OPERABLE status with its setpoint adjusted consistent with the Trip Setpoint value.

EQUATION 2.2-1 Z + R + S .<. TA 2 -

The value for column Z of Table 3.3-3 for the affected channel, R -

The "as measured" value (in percent span) of rack error for the affected channel, S-- -

Either the "as measured" value (in percent span) of the sensor error, or the value of Column S (Sensor Error) of Table 3.3-3 for the affected channel, and TA -

The value for Column TA (Total Allowance in percent of span) of Table 3.3-3 for the affected channel,

c. With an ESFAS instrumentation channel or interlock inoperable, take the ACTION shown in Table 3.3 2.

SURVEILLANCE RE00lREMENTS 4.3.2.1 Each ESFAS instrumentttion channel and interlock and the automatic actuation logic snd relays shall be demonstrated OPERABLE by performance of the ESFAS Instrumentation Surveillance Requirements specified in Table 4.3-2.

TURKEY POINT - UNITS 3 & 4 3/4 3-13

- .- _ _ _ _ _ _ _ . . _ _ _ _ .m . _ . - . _ _ . . . _ . __.. . _ _ . . 4 1

- APPs.NDIX A ~ j TAtt,E 3.3'3.

ENGINEERED SAFETY FEATURES ACTUAfl0N SYSTEM ~

< INSTRtMENTAtl0N TRIP SETPOINTS Total

Allowance - Sensor Drift Functional Unit (TA) (2) (t) Trfo tetooint Attowable Value 1

-1,15afetyinjection,(Reactor.

Trip, Turbine Trip, Feedwater

-Isolation, Control Anom isolation, start Ole et'

- Generators, Contairment

-Phase A Isolation (except -I manual $!), Contairment Cooling

- Fans, Contairnent Filter Fans, '

start $egsencer, Co m onent Cooling Water,- i

$ tert Auxillary Foodwater and

' Intake Cooling Water),

s. Manuel Initiation . NA NA kA - NA NA

b. Automatic Actuation Logic NA NA NA kA u+

c. Containment Pressure High- 2.0 0.2 0.0 3 4.0 PSIG g 5.5 P$1n

-d.'Pressurfaer Pressure' Low 13.0 8.4 1.4 -

i!G 1*" PStr

.e.1High Offferential Pressure

<l Between Steam Line '

. Header and steam Line. 4.7 1.57- 4.60

3 100 PSIG -5 114 Ps!G

-f.' Steam Line Flow

High!

16.7 2.86 3.9- 3 A function defined as '$ A function defined as -

follows: A Delta P- follows: A Delta P

-corresponding to 40% . corresponcing to 42.6%

Steam flow at 0% toad Steam Flow at 0% toad increasing linearly increasing.tinearly from frca 20% load to a value 20% toad to a value corresponding to 120% ' corresponding to 122.6%

Steam flow at full load. Steam Flow at' full load.

' Coincident-With -

Steam Generator:

Pressure

Low 13.0 1.16 = 2.3 1 614 PS!G 1 588 PSIC or .

Tavg

Low 4.0 - 2.00 1.00 t 543'F =

1 542.5'F e

12. Contairment Spray J a. Automatic Actuation Logic - __

l and Actuation Relays NA M - NA NA NA

~

'b. Contaltnent Pressure High

Hien coincident 10.0 1.6 - 0.0 5 20 PSIG .g 21.4 PGIG with Contalrunent Pressure High 2.0 0.2 0.0 1 4.0 PSIG 5 5.5 PSIG ,

- 2.3% Span for eacn sensor.

. TURKEY POINT a UNIT 5 3 & 4 3/4 3 23

, _ _ _ _ . _ _ , =_

AFP(ND!X A TABL[ 3.3 3 (Continued) l (NGINEEREO SAFETY FEATURES ACTUAi!ON SYST[M IN$iRtMNTAil0N TRIP SETPolki$

I Total Allowance Sensor Drif t functional Unit (TA) (2) ($1 Trio Seggint A ltrv&! duo

3. CONTAINMENT ISOLAi!ON

a. Phase aA" Isolation

1) Manual Initiation NA NA NA NA NA

2) Automatic Actuation kA NA NA kA kA Logle and Actuation Relays

3) tafety injection See item 1. above for et t Sa'ety Injection Trip setpointa ard Attowble Values t). Phase "B" Isolution

1) Manuel Initiation NA NA NA NA kA

2) Autanetic Actuotice kA NA NA NA Logic ord Actuation Relays

3) Contelrvnent Proesure High

Mlph Coincident 10.0 1.6 0.0 3 20 PSIG 1 21.4 P51G with Contelnment Pressure High 2.0 0.2 0.0 3 4.0 PSIG g 5.5 Ps!G

c. Containnent Ventilatim isolation

1) Contelnment teoletion Manuel Phase A or Manual Phase B RA NA NA NA hA

2) Autcenatic Actuotton NA NA NA NA NA Logte and Actuation Relays

3) safety injection see it un 1. etme for ett safety injection Trip Setpointe and Allowable Vetues

4) Conteirinent Radioactivity High NA M NA Particutetg(Rall) Particulat R 11) 5 6.1 x 10 CPM $ 6.8 x 1(,gCP(M Gaseous (R 12) see (2) Gaseous (R*12) see (2)

TURKEY PolNT UN!!S 3 & 4 3/4 3 24

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

APPENDIX A.

TABl.E 3.3 3 (Contirued)

ENGINEERID SAFETT FEATURf8 ACTUAfl0N SYSTEM INSTRLMENTAfl0N TRIP SETP0lNTS Total-Allowance Sersor crlf t Functional Unft -(TA) (2) (S) Trio SetDoint Att(wable Value

4. STEAM LINE 'SOLAf!Or

a. Manuel Initiation kA NA NA NA

b. Auttmetic Actuation NA NA NA %

Logic ard Actuati(1 Relays

c. Contaltunent Pressure Hign High coincident 10.0 1.6 0.0 g 20 PSIG g 21.4 PSIG withlContairinent Pressure High 2.0 0.2 0.0 g 4.0 PSIC g 5.5 P$lo

f. $tsam Line Flow High 16.? 2.86 3.9 3 A function defined as 3 A f metion defined as followet A Delta P followel A Delta P corresponding to 40% correspondire to 42.6% r Steam Flow at 0% toed Steam Flow at 0% load !

increening Linearly increasing linearly from fr a 20% load to e value 20% toed to a value -

corresponding to 120% corresponding to 122.6%

Steam Flow at full toed. Steam Flow at full Lond.

Coircldent witht Steam Line Pressure- Low 13.0 - 1.16 2.3 g 614 PSIG 1 588 PSIG or

.Teve

Lou- 4.0 2.00 1.00 g 543'F t $42.5'F

5. FEEWATER ISOLATION .

a. Automatic Actuatler, NA NA NA NA NA Logic and Actuation kelays

b. Safety injection - See Item 1. above for all Safety injection Trip setpoints and Alloweble Vetues

6. -Aux!tiary Foodweter (3)

a. Autanatic Actuation NA NA NA NA NA Logic ard Actuation

'Rettys ,

.b. Steam Generator Water-

= Level Low Low 5.0 2.33 1.9 1 15% of narrow g 13.2% of narroi.

range instrunent . ranee instrunent span open

~~

c . Safety injection See Item 1. above for all Safety injection Trip setpoints and Alloweble values TURKEY POINT = UNITS 3 & 4 3/4 3 25

. . ~ _ . _ _ _ . _ , .. __...-.._m.. . _ ~ . . _ _ _ . _ _ _ . . _ _ . . . ~ _ _ ._..._4 . . _ _ . . _ - _ .

APPEN0ix A TABLE 3.3 3 (Contirued)

(NGINilat0 SAFETY FEATURES ACTUAfl0N $YSTEN IN81RUNENTAfl0N TRIP sttPolNTS.

Total Allowanca Sermor Drif t functional Unit '(TA) (2) (t) frlo setooint Attowable Value 6..Auxillery feedweter (continued) 4 d4 Bus stripping See item 7. tetow for ett Bus stripping setpoints and Altowable values-

e. Trip of All Main feedwater NA NA NA NA NA Pwip Greakers 7 .Lo6s of Power.

e. 4.16 kV Busses A and B (Loss of Volt 6pe) NA NA NA NA NA

b. 480V Load Centers --

(Instantaneous Relays)

Degraded Voltage Load Center 1

3A 436V5V (10 sec 1 see eley) ( )

.38 416vi5V (10 sec 1 sec deley) ( ) ;

3C 417V15V (10 sec 1 see deley) ( )

30 428V 5v (10 sec 1 son s tey) ( )

4A 415V15V (10 eec 1 esc deley) (. 1 48- 414V 5V (10 sec : _1 sec deley) ( )

4C 401vi5V (10 sec 1 sec deley) f 1 140 -403Vi$v (10 sec 1 see deley) ( . ]

Colncident withs: . .

Safetyinjection See item 1. above for ELL Safety injection Trip setpoints and Alloweble values Diesel-Generator. NA_ NA Erecker Open-

.iUSK5Y POINT UNITS 3 & 4 - 3/4 3 26

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

- APPENDIX A TABLE 3.3 3 (Continued)

EN0!kEERED SAFETY FEATURES ACTUAfl0N $YSTEM INSittMNTAfl0N TRIP $2TPOINT5 I l

Total-Allowance Sensor Delft-Functional Unit ~ ffA) (2) f SL_ frio (etnoint Allowable Value 7.. Loss of Power (continuM)'

c. 480V Load Centers (Inverse fine Relays)

Degraded Voltept

Load Center 3A 419V5V (60 sec 30 sec deley) ( )

3B 426vi5 v :60 sec : 30 sec deley) . ( )

3C 427v:5V (60 sec 30 sec deley) I 1 30 436v:5v ( 6 sec 30'sec deley) ( )

4A- 427vi$v (60 sec : 30 sec delay) ( )

48 424Wf,5V (60 sec : 30 sec delay) [ ]

4C 413vi5V (60 sec 30 sec delay) ( )

40 412V15V (60 sec 30 sec delay) [ }

. Coincident with Diesel Generator Breaker Open . NA NA

8. Engineered Safety. features '

. Actuation System-interlocka-

ai P*11 Pressurizer Pressure NA NA NA. nominal 2000 PSIG- 1 2018 PSIG.

b. P 12 Tavg * - Low NA .NA NA w inal 543'F 542.5'F-

-9. - Control-Room Isolsticri-.

a. Automatic Actuation NA . MA - NA : NA NA Logic and Actuation' ,

Relays

b.SafetyIinjection See t_ tem 1. above for att safety injection Trip Setpoints and Allowebte Vetues

--TURXEY POINT = UNITS 3 & 4 3/4 3 27-

APPfMDix A

' TABLE 3.3 3 (Continued)

EliC1HEERED SAff fY FEAfutt$ ACTUATION SYSTEM INSTRG4ENTAfl0N TRIP SETPolNTS ec -

fote!

., . _ A!!owance Sensor Drift functionel Unit _ (TA) (2)- (si Trio Setooint= Attouable Vetue q ;. 9.-' Control Room isolation (Continued)

, c. Contairvant.

Radioactivity High (1) NA - NA NA Particulatg(R11) Particulatg(R11)

$ 6-,1 x 10 CPM 3 6.8 a 10 CM Gesecue (R 1?) see (2) Gaseou, (R 12) see (2)

d. Containment Isolation Manuel Phase A or' NA NA NA NA NA

Manuel Phase B

.e. Air IntMo Radiation -

. Level kA hA NA g 2.83ndt/hr 3 2mR/hr

. TABLE NOTA 7!ONS i.

-(1) Either the perticulate or puseous channe; n the OPERABLE atatus will setlefy this LCO.

. x 0 ' ) CPM, (2) Conteirwent Gaseous Monitor Setpoint * -

(f)

~

ContalrinentGeseous Monitor Allowable Value =CPM, (3 + 10 ' i (F) l g, , ; Actual ourne Flow

'+

Design Purgo flow (35,000 CfM)

Setpoint may very according to current plant conditions avited that the release rate < toes

-K-not exceed allowable limits provided in Specification 3.11.2.1.

f (3) Auxillary feedwater marual initiation Is i.ncluc;ed in specification 3.7.1.2.

!f no at townEie value is specified so irdicated try ( - ), the trip setpoint

.shalt:also be the allowable value. '

E i

TURKEY POINT UNITS 3 & 4 3/4 3*26-w n , , - - , . , y n ,u a- --.

y - ,-- .

APPENDIX A 3/4.3 INSTREENTATION M ES 3/4.3.1 and 344.3.2 REACTOR TRIP SYSTEM and ENGINfERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION The OPEPABILITY of the-Reactor Trip System and the Engineered Safety Features Acteation-System instrumentation and interlocks ensures that: (1) the associated ACTION and/or Reactor trip will be initiated when the

-parameter monitored by each channel or combination thereof reaches its Setpoint (2) the specified coincidence logic is maintained. (3) sufficient redundance is maintained to permit a channel to be out-of-service for testing or inaintenance (due to plant specific design, pulling fuses and using jumpers may be used to. place channels in trip), and 4 sufficient system functional capability is available from diverse para (me)ters.

The OPERABILITY of these systems it, required to provide the overall reliability, redundancy, and diversity assumed available in the facility design for the protection and mitigation of accident and transient '

conditinns. The integrated operation of- each of these ' systems is consistent with the assumptions used in the safety analyses. The Surveillance Requirements specified for i.hese systems ensure that the overall system functional capability is maintainsd comparable to the original design standards. .The periodic ~ surveillance tests performed at the mintimum frequencies are sufficient to demonstrate this capability.

The Engineered Safety Features Actuation System Instrumentation Trip Setpoints specified in Table 3.3-3 are the nominal values at which the bistables-are set for each functional unit. The setpoint is considered to be adjusted consistent with the no:ninal value when the "as measured" setpoint is within the band allowed for calibration accuracy.

To accommodate the instrument drift t'at may occur between. operational 1 tests and the-accuracy to which Set)oints can be measured and calibrated, Allowable Values for the Setpoints lave been specified in Table 3.3-3.

Oporation with Setpoints less conservative than the Trip Setsoint but

- within the Allowable Value is acceptable since an allowanct ns been made in~the safety. analysis to accommodate this error.- An optional provision

.has been included fo* determining the OPERABILITY of a channel when its trip ~ setpoint is fourd to exceed the Allowable Value. The methodology of this option utilizes the "as measured" ("as found" deviation from the specified calibrati(n point for rack and sensor components in conjunction with a statistical' combination-of the other uncertainties of the instrumentation to measure the process variable and thei uncertainties in

-calibrating the instrumentation. In Equation 2.7.-1,'2 + R + S 1 TA, the interactive effects of'the errors in the rack and the sensor, and the "as measure" values of the errors are considered. Z, as specified in Table 3.3-3, u percent span, is the statistical summation of errors assumed TURKEY POINT - UNITS 3 & 4 8 3/4-1

]

APPENDIX A 3/4 INSIEUMENTATION M-2/4.3.1 and 3/4.3.2 REACTOR TRIP SYSTEM and ENGINEERED SAFETY FEATURES fflyATION SYSTEM INSTRJ)KENTATION (Continued) in the analysis excluding those associated with the sensor and rack drift and the accuracy of their measurement. TA or Total Allowance is the difference, in percent span, between the trip setpoint and the value used in the analysis for actuation. R or Rack Error is the "as measured" ("as found" - nominal) devit. tion, in percent span, for the affected channel from the specified trip setpoint. S or Sensor Orift is either the "as measured" ("as found" - nominal) deviation of the sensor from its calibration point or the value specified in Table 3.3-3, in percent span, from the analycis assumptions. Use of Equation 2.2-1 allows for a sensor drift factor, an increased rack drift- factor, and provides a thresheld value for determining reportability.

The methodology to derive the Trip Setpoints includes an allowance for instrument uncertainties. Inherent to the determination of the l Trip Setpoints are the magnitudes of these channel uncertainties. ,

Sensor and rack instrumentation utilized in these channels are l expected to be capable of operating within the allowances of these uncertainty magnitudes.

Rack drift in excess of the Allowable Value exhibits the behavior that the rack has not met its allowance. Being that there is a small statistical chance that this will happen, an infrequent excess 1"e drift is expected. Rack or sensor drift, in excess of the allowoce that is more than occasional, may be indicative of more serious problems and should warrant further investigation.

5 TURKEY POINT - UNITS 3 & 4 8 3/4-1 (cont'd)

C

ML20072Q579

Text

1.0 INTRODUCTION

1.0 INTRODUCTION

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