ML17324A754

Nonproprietary American Electric Power DC Cook Unit 2 Rdf RTD Installation Safety Evaluation

ML17324A754
Person / Time
Site:	Cook
Issue date:	02/28/1986
From:	Moomau W, Tuley C WESTINGHOUSE ELECTRIC COMPANY, DIV OF CBS CORP.
To:
Shared Package
ML17324A753	List: ML17324A752 ML17324A754 ML17334A951
References
WCAP-11081, NUDOCS 8604070065
Download: ML17324A754 (28)

Text

WCAP-11081 WESTINGHOUSE PROPRIETARY CLASS 3 AMERICAN ELECTRIC POWER D.

C.

COOK UNIT 2 RDF RTD INSTALLATION SAFETY EVALUATION W.

H.

Hoomau C.

R. Tuley

February, 1986 Worked performed under project AUGP-487 Westinghouse Electric Corporation Nuclear Energy Systems P.O.

Box 355 Pittsburgh, Pennsylvania 15230 8604070065 8 0327

)

PDR ADOCK 050003i6 l

P

, 'DR

WESTINGHOUSE PROPRIETARY CLASS 3 TABLE OF CONTENTS SECTION TITLE PAGE 1.0 2.0 3.Q Sugary DiSCUss ion Conclt.s;on

MESTINGHOUSE PROPRIETARY CLASS 3 LlST OF TABLES TITLE Overtemperature Delta-T Trip Overpower Delta-T Trip Tavg Lcw-Lcw Trip Lcw Fla Reactor Trip Pressurizer Pres ure Control System Accuracy Rod Control System Accuracy Indicated Tavg, for DUB Technical Specification Limit Pressurizer Pressure High Steam Generator i.evel - Lcu-Lcw Revised Technical Specification Tables Table 2.2-1 Reactor Trip System Instrumentation Trip Setpoints Table 3.2-1 DNB Paraneters Table 3.3-4 Engineered Safety Feature Actuation System Instrumentation Trip Setpoints 1

1 1lli lv V

Vlvil V111 1X XV XV1

WESTINGHOUSE PROPRIETARY CLASS 3 AHERXCAN E.ECTRIC POWER D.

C.

COOK UNlT 2 RDF RTD INSTALLAT>GN SAFETY EVALUATION 1

~ 0 REEVE These are the results of the D.

C.

Cook Unit 2 safety evaluation for the insta11azion of RdF RTDs for fuel cycle six.

This evaluation demonstrates that the znstallation of RdF RTDs (with ircreased and reallocatea uncertainties over the currently installed RTDs) will not impact the Safety Aralysis Limits

assumed, nor the core limits utilized, in the plant's safety analyses.

The only significant changes to the plant are the Allcwable Values fcr several protection functions and the irdicated Tavg values in the Unit 2 Technical Specifications.

Ncmiral Trip Setpoints in the Technical Specifications remain as specified by the fuel vendor.

2.0

~DI CgggQg At the request of American Electric Power, Westinghouse investigated the impact of the change from Rosemount to RdF RTDs on the D.

C.

Cook Unit 2 plant.

This investigation involved two parts, the first being a determination of the uncertainties for those protection and control functions impacted by the use of the RTDs.

The second was an evaluation of the impact of those instrunent uncertainties on the plant's safety analyses.

Finally, the Technical Specifications were reviewed for impact and change recommendations were made for the areas. affected.

In the recent months, Westinghouse has performed a considerable amount of work in the determination of revised uncertainties for RdF RTDs when it was learned that the calibration accuracy used in the setpoint studies for several plants was not being met.

As a result of thi,s work, Westinghouse has determined the calibration of the RTD under the RdF calibration laboratory conditions and revised the analysis procedure for evaluation of RTD cross calibration data taken during plant heat-up.

The end product of the revised analysis procedure is the verification that each RTD installed in the plant meets a total uncertainty assumption of [

+a,c

WESTINGHOUSE PROPRIETARY CLASS 3 This uncertainty is composed of [

For ease of calculation in the Westinghouse methodology, the total uncertainty was split into two parts, an

+a~ c

+ay c SCA value of [

] 'nd an SD value of [

These RTD uncertainties and the mcertairties far the Foxboro pressure transaiitter provided by AEP were then used in the standard Westinghouse methodology for the calculation of instrunent channel uncertainties, i.e.,

the same methodology used for Westinghouse Statistical Setpoint Studies and Improved Thermal Design Procedure (ITDP) instranent uncertainty calculations.

The following protection and control function instrument mcertainties were evaluated; Overtemperature Delta-T, Overpower Delta-T, RCS Law Flaw Trip, Lm-Lcw Tavg, Rod Control (Tavg input,), Pressurizer Pressure

Control, and RCS Precision Flaw Calorimetric measurement uncertainty.

For the protection functions it was determined that the Safety Analysis Limit/Nominal Trip Setpoint relationship was sufficient to accommodate the changed uncertainties without causing changes to the vendor-specified SAL or Nominal Trip Setpoint.

However the Allowable values for these functions should be changed as indicated belm:

Overtemperature Delta-T Overpower Delta-T Loss of Flaw Tavg Lnr-Law 4% Delta-T span 4'$ Delta-T span 89% design flaw 539 degrees-F 3.3$ Delta-T span 2.6$ Delta-T span 88.9$ design flaw 538.2 degrees-F Pages (i), ('ii), (iii), and (iv) list the uncertainties in percent of instrunent span that were used in the development of the new allowable values.

Far the control functions and the reactor coolant system (RCS) flow calorimetric uncertainty the original instrunent uncertainties and the revised

WESTINGHOUSE PROPRIETARY C'SS 3

values a> e listed belcw.

Pages (v) and (vi) list the mcertainties in per cent of instrunent span that were used in the development if the total controller uncertainties.

Pressurizer Pressure Control

+a,c Rod Control (temperature)

RCS Flew Calorimetric Bm~

Pressurizer Pressure Control

+a,c Rod Control (temperature)

(2)

RCS Flew Cala imetric (3)

( 1) Due to change to Foxboro transmitters.

(2) Due to change to RdF RTDs.

(3) Due to changes to RdF RTDs and Foxboro transmitter.

The DNB Paraneters specification (Table 3.2-1) limit for Tavg was recalculated and the old and new values are listed belm.

WESTINGHOUSE PROPRIETARY CLASS 3 N~od o

~0 0 loops 6 RATED THER@4~.

FCWER 576.7 degrees-F 576.3 deg. ees-F Page (vii) lists the uncertaintie in percent of instrument span ard the procedure used in tne development o: tne raw value.

The pressurizer pressure - high and steam generator water level lcw-lcw chanrel uncertainties were recalculated for the change to Foxboro pressure transmitters.

It was determined that the Safety Analysis Limit/Naairal Tr'p Setpoint relationship was sufficient to accommodate the changed uncertainties without causing changes to the Safety Analysis Limit or Nominal Trip Setpoint.

The Allowable Values were also recalculated for these functions and the old and new values are irdicated belcw:

Pressurizer Pressure High Steam Generator Water Level - Lnt-Lm 2395 psig 20$ of narrow range span 2395 psig 19.2% of narrow range span Pages (viii) and (ix) list the uncertainties in percent of instrunent span that were used in the development of the new allowable values.

, 3 0 KHQJlSIQH In conclusion, it can be stated that the only impact on the plant due to the installation of RdF RTDs and Foxbor o transmitters is the changing of the M.liable Values for the protection functions indicated and the Table 3.2-'t Tavg value in the D.

C.

Cook Unit 2 Technical Specifications.

Attached are the pages of the Technical Specifications that require modification.

HtbllHbHVUSE PROPRIETARY CLASS 3 OVERTEMPERATUR-DELTA-T TRIP DELTA-7 Tavg PRESS DELTA-I FMA SCA M4~TE=

STE cD

&I AS=

MhTE=

M~TE=

RCSA=

INSTRUMENT SPAN 93.9 DEGF (150% Power)

SAFETY ANALYSIS LIMIT

= I ~ 3918 ALLOWABLE VALUE 3.26

% DELTA-T SPAN ya C.

MAXIMUM VALUE NOMINAL TRIP SETPOINTS VESSEL DELTA-T ~

62 6 DEGF DELTA-I GAIN ~ 2. 28

/gal~ C Kl = 1. 2598 K3 ~ 8. 888744 04)C S ~

245 TA ~

8.88 Z =

4 ~ 98 g+r~ c

WESTINGHOUSE PROPRIETARY CLASS 3 OVERPOWER DELTA-T TRIP DELTA-T Tavg SCA SD BIAS=

M9>>TE~

M~TE=

RCSA=

RD INSTRUMENT SPAN SAFETY ANALYSIS LIMIT OL4ASLE VALUE MAXIMUM VALUE NOMINAL TRIP SETPOINT

. 9 DEGF (150'ower) 1 ~ 1528 2.57

% DELTA-T SPAN3

K4 ~ 1. 8788 VESSEL DELTA-T ~

t~<j's TA >

4.93 1 ~ 85 Z K 1 ~ 47 62 6 DEGF

+r. C

2. 57

('JEBT II161<GUSE PRQPf(IETARY CLASS

= T=-.-o-LG1!-LGN rl=:IP Pl<A C,f'g

- ~

pg 4E I i!'=:Tr.Ut'lEN7 f':Af'!i~E INGTfi"il lEI'lT SPAN

~Al"ETY ANAL%S I~ LI 5 I 'I ALLONA&LE VALUE t'1 AX 1 NUN VALUE

-"'.-""0 TO e '5. 0 DE&F' 00, Ij D} {j[

~i, i7. 0 DEAF 5 8.2 DEGF gfQ)6 NOVIl'lAL TR IP SETPO I NT fA C 5

=

0.87 Z

511.0 DEAF

0. 8>

TA =

4.00

ir LOW FLOW REACTOR TRIP DP SPAN FLOW SPAN C

t4)

MA2 PEA SCA SPE STE SD BIASF'=

BIAS1=

BIAS2=

RCA MbTE RCSA ~

BIAS ~

INSTRUMENT RANGE FLOW SPAN 8 TO 118.8 / FLOW 118. 8 / FLOW SAFETY ANALYSIS LIMIT ~

87. 8

% FLOW ALLOWABLE VAI UE MAXIMUM VALUE 88 ~ 9

% FLOW

+hi C.

NOMINAL TRIP SETPQINT g5 C t

3 S - 8.-.5 TA = 2 ~ 73

98. 8

% FLOW Z ~

1.54

+ROC

~ ~ ~ v

~

~

~ ava rvv a Ilv'I I%i I

I ~ I VvPI et PRESSURlZER PRESSURE CONTROL SYSTEM ACCURACY SCA N';cTE=

STE N'<TE=

ELECTRONICS CSA CONTROLLER CSA

]

ROD CONTROL SYSTEM ACCURACY SCA Tavg TURB PRES pa c.

MbTE=

BIAS=

RCA c M4cTE=

MbTE=

RTE RD CA BIAS=

ECTRONICS CSA ELECTRONICS SIGMA CONTROLLER SIGMA CONTROLLER CSA

WESTINGHOUSE PROPRIETARY CLASS 3 ZndicahsAZ-Tavg span CSA PVA

+ay c IR (indicator readability )

'CSA

=

[

)+a,c 3

16 Assuming three (3) Tavg channels for averaging, CSA = [

)+a,c 1 8$

DNB Technical Specification Limit =

)+a) c Full Power Tavg

= 574.1 degrees-F (at 3411 N)

DNB Technical Specification Limit = [

]

576.3 degrees-F

a.

PRESSURIZER PRESS.

HIGH FQXBORO TRANSMITTER WESTINGHOUSE PROPRIETARY CLASS 3

~ 0~C SPE S

E SD EA BIAS=

RCA RCSA=

RTE RD INSTRUMENT RANGE TRUMENT SPAN 85 SAFETY ANALYSIS LIMIT ~

ALLO@ABLE VALUE MAXIMUM VALUE NOMINAL TRIP SETPOINT ~

qg C

3 S

~

150 1700.00 TO 800.00 PSIG 2410. 00 PS IG 2595. OZ PSI6 3

2~85 00 PSIG 2500. 00 PS I6 gy a~C

STEAM GEN MODEL 51 PMA ~

WESTINGHOUSE PROPRIETARY CLASS 3 LEVEL-LOW-LOW SG, FOXBORO XMITTER PEA SCA SPE BIAS=

R A

RCSA=

RTE RD INSTRUMENT RANGE INSTRUMENT SPAN SAFETY ANALYSIS LIMIT ~

ALLOWABLE VALUE MAXIMUM VALUE NOMINAL TRIP SETPOINT

0. 00 TO 100. 00

% SPAN 0.00

% SPAN 19 25

% SPAN

21. 00

% SPAN 100. 00 SPAN

)

+ 4~ C TA ~ 21.00

+A)C S

1.50 Z

~

7.35 T

~

1.75

)

+4~C

]pa>C

CD TABLE 2.2-1 REACTOR TRIP SYSTEH INSTRUHENTATION TRIP SETPOINTS n

CD CD PC I

FUNCTIONAL UNIT

1. Hanual Reactor Trip 2.

Power Range, Neutron Flux 3.

Power Range, Neutron Flux, High Positive Rate 4.

Power Range, Neutron Flux, High Negative Rate

5. Intermediate

Range, Neutron Flux

6. Source

Range, Neutron Flux TRIP SETPOINT Not Applicable Low Setpoint -

< 25K of RATED THERHAL POWER High Setpoint - < 109K of RATED THERHAL POWER 5% of RATED THERMAL POWER wi.th a time constant

> 2 seconds 5% of RATED THERHAL POWER with a time constant

> 2 seconds

< 25'f RATED THERHAL POWER

< 10 counts per second 5

ALLOWABLE VALUES Not Appl icabl e Low Setpoint -

< 26K of RATED THERHAL POWER High Setpoint -

< llGX of RATLD THERMAL POWER 5.5'.C of RATED THERHAL POWER with a time constant

> 2 seconds

< 5.5X of RATED TH<RHAL POWER with a time constant

> 2 seconds

< 30K of RATED THERHAL POWER

< 1.3 x 10 counts per second 5

7. Overtemperature hT See Note 1

8. Overpower hT See Note 2

9. Pressurizer Iiressure-Low

> 1950 psig

10. Pressurizer Pressure High

< 2385 psig ll. Pressurizer Mater LevelHigh

< 92K of instrument span See Note 3

See Note 4

> 1940 ps ig

< 2395 psig

< 93K of instrument span

12. Loss of Flow

> 90K of design flow per loop*

88.9;" Gt design flow per loop*

'lleslgn floe Is 93,I'D pied per lou)).

n n

C)

C3 PC FUNCTIONAL UNIT TABLE 2.2-1 Continued

. REACTOR TRIP SYSTEH INSTRlNENTATION TRIP SETPOINTS TRIP 'ETPOINT ALLOWABLE VALUES I

Ch

13. Steam Generator Mater Level - Low-Low

14. Steam/Feedwater Flow Mismatch and Low Steam

'enerator Mater Level

15. Undervoltage - Reactor Coolant Pumps

16. Underfrequency - Reactor Coolant Pumps

17. Turbine Trip A.

Low Trip System Pressure 8.

Turbine Stop Valve Closure

18. Safety Injection Ihput from ESF 21%of narrow range instrument span - each steam generator

< 1.47 x 10 lb/hr of steam flow at RATED THERMAL POWER coincident with steam generator water level

> 25K of narrow range instru-ment span - each steam generator

> 2750 volts - each bus

> 58.2 Hz - each bus

> 5& psig

> 1X open I

Not Applicable

19. 2X of narrow range instrument span

-. each steam generator

< 1.56 x 10 lbs/hr of steam flow 6

at RATED THERHAL POWER coincident wi th steam generator water level 24% of narrow range instru-ment span

- each steam generator

> 2725 volts - each bus

> 58.1 Hz - each bus 57 psig 1X open Not Appl lcable

19. Reactor Coolant Pump Breaker Position Trip Not Applicable Not Applicable

TABLE 2.2-1 Continued REACTOR TRIP SYSTEH INSTRUHENTATION TRIP SETPOINTS NOTATION NOTE 1:

Overtemperature hT < hT fK1-K2' tT-T )+K3tP-P )-fl(AI)]

l+,,s where:

hT0 T

~

p Indicated hT at RATED THERHAL POWER Average temperature,

'F Indicated T at RATED T}IERHAL POWER (provided by Exxon)

Pressurizer

pressure, psig P

~

2235 psig tindicated RCS nominal operating pressure) 1+rlS l~r~s

~l

~ ~2 The function generated by the lead-lag controller for T dynamic compensation avg Time constants utilized in the lead-lag controller for Tav Tl 33 secs, v2 ~ 4 secs.

avg 1

Laplace transform operator

C3 C) amg I

C Operation with 4 Loops Operation with 3 Loops TABLE 2.2-1 Continued)

REACTOR TRIP SYSTEM INSTRUMENTATION TRIP SETPOINTS NOTATION Continued K2 0.01607 K3

~ 0.000744 Kl (not provided)

K2 es 0.01607 K3

= 0.000744 gagI CQ and f (sl) is a function of the indicated difference between top and bottom detectors of th) power-range nuclear ion chambers; with gains to be selected based on measured instrument response during plant startup tests such that:

(i) for'q - q between - 40 percent and + 3 percent, f( (hl) = 0 (where q hand q

are percent RATED THERMAL POWER in the top and bottom halves of the cire respectively, and q

+ qb is total THERMAL POWER in percent of RATED THERMAL POWER).

(ii) for each percent that the magnitude of (q

- q

) exceeds

- 40 percent, the aT trip setpoint shall be automaticalfy reIIuced by 1.8 percent of its value at RATED THERMAL POWER.

(iii) for each percent that the magnitude of (q

- q

) exceeds

+ 3 percent, the aT= trip setpoint shall 4e automatica1)y reIIuced by 2.2 percent of

.its value at RATED THERMAL POWER.

Cl C

Note 2.

TABLE 2.2-1 Continued REACTOR TRIP SYSTEH INSTRUHENTATION TRIP SETPOINTS NOTATION Continued t3S Overpower hT < hT IK4-K5 ~+S T - K6 (T-T")-f2(hl)]

"3'here:

hT

~

Indicated hT at rated power T

Average temperature,

'F TN K4 Indicated T

at RATED THERHAL POWER

< (P<<>><<d by E>><<)

avg 1.078 KS

~

0.02/'F for increasing average temperature and 0 for decreasing average temperature K6 0.00197 for T > T"; K6 0 for T T"

t3S

~+~3S t3 S

The function generated by the rate lag controller for T dynamic compensation avg Time constant utilized in the rate lag controller for T c3 10 secs.

avg Laplace transform operator Note 3:

Note 4:

f (aI)

(provided hy Exxon)

The channel's maximum trip point shall not exceed 3.3 percent.

The channel's maximum trip point shall not exceed 2.6 percent.

its computed trip point hy more than its computed trip point by more than

IINII PAEAHI!TR[L I.INIT!i PAAAHETVA Reactor Coolant Systra T~+'

Pressurizer Pressuru inn it> In l)~w.I'al inn 5>6 ~ 3 "

(indicated) 2220 Icosi.>'

I~is Ln 0 aration~~~.

(not nrovided)

L

> 2220 psla~

44 xC I

a Limit not applicablc Burin<) uitlier a TIIRIIHAI, POMER raeP I<<" cs yoga:R per alnute nr a 'fjlRQ4AI. PggEg step in excess of 10%

~ a Indicated average vf OPEAhAl.t; instrueent

)oons.

lt sbnukd be nota:d g)mt Ll>rue loop npa.r:

in us)ncaa t)>is curve is nr t currently a?,1c cslilnill's con t'ai l nusl I n Llii s I esl ~l0 are foc

~u' or~.net on 1 y.

~ ~

~

1

!=.

'=,

-"-TABLE-3.3-4; Cohtinue ENGINEKREO=SAFETV='FEATURE'ACTUATION-SYSYN

'4 UH6riAtiON.-TRIP

/-

SETPOINTS FUNCTMNAL UNIT TRIP SETPOINT ALLOMABLEVALUES 4.

STEN LINE 'ISOLATION a.

Manual b.

Automatic Actuation Logic c.

Containment Pressure-High-High d.

Steam Flow in Two Steam lines-High Coincident with T

--Low-Low avg Not Applicable

.Not Applicable

< 2.9 psig

< A function defined as 7ollows:

A ap co~respond-ing to 1.47 x 10 lbs/hr steam flow between OX and 20K load and then a Ap increasing linearly to a ap corresponding to ll05 of full steam flow at full load.

T

> 541'F avg Not AppIicable Not Applicable 3.0 psig

< A function defined as fol1ows:

A (p corresponding to 1.62 x 10 lbs/hr steam flow between OX and 20% load and then a hp increasing.1'inearly to a ap corresponding to ill.SX of full steam flow at full-load.

7 538.2'F avg e.

Steam Line Pressure--Low

> 600 psig steam Tine pressure 5SO psig steam Tine pressure 5.

TURBINE TRIP AND FEED MATER ISOLATION a.

Steam Generator Mater level-High-High

> 67K of narrow range

> 6SK of narrow range

'nstrument span each steam instrument span each steam generator generator

~tl> ',) ~r>>

I I

))',~

)C'.

4.

I l

.'))~'), "

LIwQ r L~

II ~ J l

)

fl

).)r>

j )

3>>. )

fg,)

I

r:;lt'

)

I

~

I

)

I)', ~ J.

Wl 1

t C ')

(

II;.

'." k, VA "r,

~

Jy

)

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