ULNRC-05192, Supplemental Technical Specification Revisions for the Steam Generator Replacement Project

Supplemental Technical Specification Revisions for the Steam Generator Replacement Project

ML052630485
Person / Time
Site:	Callaway
Issue date:	09/06/2005
From:	Keith Young AmerenUE
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
ULNRC-05192
Download: ML052630485 (74)

Text

AmerenUE Callaway Plant PO Box 620 Fulton, MO 65251 September 6, 2005 U.S. Nuclear Regulatory Commission Attn: Document Control Desk Mail Station PI -137 Washington, D.C. 20555 ULNRC-05192 Ladies and Gentlemen:

DOCKET NUMBER 50-483 UNION ELECTRIC COMPANY CALLAWAY PLANT SUPPLEMENTAL TECHNICAL SPECIFICATION REVISIONS FOR THE wAmeren STEAM GENERATOR REPLACEMENT PROJECT UE IAr t

ITT 'KTT'h/'

fllr K Ar 2

Its 17

• AnnA Reierences;

1. ULINISU-UjUDO aaLeu OepLerioer I /, -Uu'+

2. ULNRC-05117 dated February 11, 2005

3. ULNRC-05145 dated May 26, 2005

4. ULNRC-05157 dated June 17, 2005

5. ULNRC-05159 dated June 17, 2005

6. ULNRC-05169 dated July 15, 2005

7. ULNRC-05178 dated July 29, 2005

8. ULNRC-05188 dated August 16, 2005 AmerenUE herewith transmits a supplement to the application for amendment to Facility Operating License Number NPF-30 for the Callaway Plant that was originally submitted via Reference I above, and supplemented in Reference 4, in support of the replacement steam generators to be installed during Refuel 14 (fall 2005). The required supplement to the Technical Specification (TS) changes requested in References 1 and 4 involves TS Tables 3.3.1-1 and 3.3.2-1. Footnotes had previously been added to those TS tables in Reference 4 to reflect the RTS and ESFAS setpoint restoration commitments submitted in Reference 3. Based on several discussions with NRC staff between July 27 and September 1, 2005, this supplement revises those same footnotes to include additional requirements deemed necessary by the NRC.

In addition, INSERT B 3.3.1.C in Attachment 4 of Reference I on the low RCS flow reactor trip Bases has been revised to read as follows:

"At the beginning of each cycle the plant will normalize the RCS flow transmitters during zero power, normal operating pressure, normal operating temperature (NOP/NOT) conditions such that they indicate at 100% flow in each respective loop. This normalization is then verified prior to exceeding 75% of RATED THERMAL POWER and again after reaching full power following a refueling outage when suitable plant conditions are established. The bistables for the low RCS flow trip function are a subsidiary of Ameren Corporation

ULNRC-05192 September 6, 2005 Page 2 calibrated separately to verify that they are set at the nominal trip setpoint of 90% of indicated loop flow. The nominal trip setpoint is based on the loop-specific normalized flow input (i.e., the indicated loop flow) from each of the three RCS flow transmitters per RCS loop."

There are no new changes to the revised Evaluation provided in Reference 4 which had previously submitted changes to the Reference 1 Evaluation. Attachments 1 through 3 provide the Markup of Technical Specifications, Retyped Technical Specifications, and Proposed Technical Specification Bases Changes, respectively, in support of this supplemented amendment request. Attachment 3 is provided for information only. Final Bases changes will be implemented pursuant to TS 5.5.14, Technical Specifications Bases Control Program, at the time the amendment is implemented. There are no new commitments contained herein.

It has been determined that the nature of the TS changes contained in this supplement does not invalidate the findings of the licensing evaluations contained in of Reference 1. The amendment application, as supplemented, does not involve a significant hazard consideration as determined per 1 OCFR50.92 nor is there a requirement to prepare an environmental impact statement or environmental assessment.

The Callaway Onsite Review Committee and Nuclear Safety Review Board have reviewed and approved the submittal of this supplement. The implementation plans for this amendment application remain unchanged from Reference 1. In accordance with I OCFR50.91, a copy of this amendment application supplement is being provided to the designated Missouri State official.

If you have any questions on this amendment application, please contact me at (573) 676-8659, or Mr. Dave Shafer at (314) 554-3104.

I declare under penalty of perjury that the foregoing is true and correct.

Very truly yours, Executed on: September 6, 2005 Y

Manager-Regulatory Affairs GGY/

Attachments:

I Markup of Technical Specifications 2

Retyped Technical Specifications 3

Proposed Technical Specification Bases Changes (for information only)

ULNRC-05192 September 6, 2005 Page 3 cc:

U.S. Nuclear Regulatory Commission (Original and I copy)

Attn: Document Control Desk Mail Stop P1-137 Washington, DC 20555-0001 Mr. Bruce S. Mallett Regional Administrator U.S. Nuclear Regulatory Commission Region IV 611 Ryan Plaza Drive, Suite 400 Arlington, TX 76011-4005 Senior Resident Inspector Callaway Resident Office U.S. Nuclear Regulatory Commission 8201 NRC Road Steedman, MO 65077 Mr. Jack N. Donohew (2 copies)

Licensing Project Manager, Callaway Plant Office of Nuclear Reactor Regulation U. S. Nuclear Regulatory Commission Mail Stop 7EI Washington, DC 20555-2738 Missouri Public Service Commission Governor Office Building 200 Madison Street P.O. Box 360 Jefferson City, MO 65102-0360 Deputy Director Department of Natural Resources P.O. Box 176 Jefferson City, MO 65102

ATTACHMENT 1 MARKUP OF TECHNICAL SPECIFICATIONS

RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 1 of 8)

Reactor Trip System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE<')

1.

Manual Reactor 1,2 2

B SR 3.3.1.14 NA Trip 5 b p3(), 4(b) 5(b) 2 C

SR 3.3.1.14 NA

2.

Power Range Neutron Flux

a. High 1,2 4

D SR 3.3.1.1

• 112.3% RTP SR 3.3.1.2 SR 3.3.1.7 SR 3.3.1.11 SR 3.3.1.16

b. Low 1(c),2 4

E SR 3.3.1.1

< 28.3% RTP SR 3.3.1.8 SR 3.3.1.11 SR 3.3.1.16

3.

Power Range 1,2 4

E SR 3.3.1.7

• 6.3 % RTP Neutron Flux SR 3.3.1.11 with time Rate - High SR 3.3.1.16 constant Positive Rate 2 2 sec

4.

Intermediate 1(c), 2(d) 2 F, G SR 3.3.1.1

• 35.3% RTP Range Neutron SR 3.3.1.8 Flux SR 3.3.1.11 (continued)

I (a)

(b)

(c)

(d)

The Allowable Value defines the limiting safety system settingyoee the Bases for the Trip Setpoints.

With Rod Control System capable of rod withdrawal or one or more rods not fully in rted.

Below the P-10 (Power Range Neutron Flux) interlock.

/

Above the P-6 (Intermediate Range Neutron Flux) interlock.

/klom,/t,.

/

CALLAWAY PLANT 3.3-17 Amendment No. 151

I.

INSERT 2 except for Trip Functions 14.a and 14.b (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions).

RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 2 of 8)

Reactor Trip System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE°8'

5.

Source Range 2('e 2

I,J SR 3.3.1.1 s 1.6 E5 cps Neutron Flux SR 3.3.1.8 SR 3.3.1.11 3(b) 4(b) 5(b) 2 J, K SR 3.3.1.1 s 1.6 E5 cps SR 3.3.1.7 SR 3.3.1.11

6.

Overtemperature 1,2 4

E SR 3.3.1.1 Refer to Note 1 AT SR 3.3.1.3 (Page 3.3-23)

SR 3.3.1.6 SR 3.3.1.7 SR 3.3.1.10 SR 3.3.1.16

7.

OverpowerAT 1,2 4

E SR 3.3.1.1 Refer to Note 2 SR 3.3.1.7 (Page 3.3-24)

SR 3.3.1.10 SR 3.3.1.16

8.

Pressurizer Pressure

a.

Low i(q) 4 M

SR 3.3.1.1 21874 psig SR 3.3.1.7 SR 3.3.1.10 SR 3.3.1.16

b.

High 1,2 4

E SR3.3.1.1 s2393psig SR 3.3.1.7 SR 3.3.1.10 SR 3.3.1.16 (a)

(b)

(e)

(g)

The Allowable Value defines the limiting safety system setting/See the Bases for the Trip Setpoints.

With Rod Control System capable of rod withdrawal or one or more rods not fully insrted.

Below the P-6 (Intermediate Range Neutron Flux) interlock.

l Above the P-7 (Low Power Reactor Trips Block) interlock.

NO MfnA /

(continued)

CALLAWAY PLANT 3.3-1 8 Amendment No. 133

INSERT 2 except for Trip Functions 14.a and 14.b (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions).

RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 3 of 8)

Reactor Trip System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUES)

9.

Pressurizer Water 1(9) 3 M

SR 3.3.1.1

< 93.8% of Level - High SR 3.3.1.7 instrument SR 3.3.1.10 span

10.

Reactor Coolant 1N) 3 per loop M

SR 3.3.1.1 2 88.8% of Flow - Low SR 3.3.1.7 indicated loop SR 3.3.1.10 flow SR 3.3.1.16

11.

NotUsed

12.

Undervoltage IN) 2ibus M

SR 3.3.1.9 2Ž10105 Vac RCPs SR 3.3.1.10 SR 3.3.1.16

13.

Underfrequency IN) 2lbus M

SR 3.3.1.9 2 57.1 Hz RCPs SR 3.3.1.10 SR 3.3.1.16

14.

Steam Generator (SG) Water Level Low-Low")

a. Steam 1,2 4 per SG E

SR 3.3.1.1 2 20.6%(q) of Generator SR 3.3.1.7 Narrow Range Water Level SR 3.3.1.10 Instrument Low-Low SR 3.3.1.16 Span (Adverse Containment Environment)

b. Steam 1(P),2(P) 4 per SG E

SR 3.3.1.1 2 16.6%(q) of Generator SR 3.3.1.7 Narrow Range Water Level SR 3.3.1.10 Instrument Low-Low SR 3.3.1.16 Span (Normal Containment Environment)

(continued)

=A1,rCR-a (a) The Allowable Value defines the limiting safety system settingySee the Bases for thTrip Setpoints.

(g) Above the P-7 (Low Power Reactor Trips Block) interlock.

(I)

The applicable MODES for these channels in Table 3.3.2-1 are more restrictive. Mon;,n4 /

(m) Not used.

(p) Except when the Containment Pressure - Environmental Allowance Modifier channels in the same protection sets are tripped.

(q) cg ou itwo-side libration tolarrce band, channe s trip se nsall be res to withi as-lef calaipi eand on eitjde of the inal Trip Sp~iiit hd in atance with lant setpoin hodoloq rotect thea¶tv analvsvit CALLAWAY PLANT 3.3-19 Amendment No.

INSERT 1

1. If the as-found instrument channel setpoint is conservative with respect to the Allowable Value, but outside its as-found test acceptance criteria band, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. If the as-found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.

2. The instrument channel setpoint shall be reset to a value that is within the as-left setpoint tolerance band on either side of the Nominal Trip Setpoint, or to a value that is more conservative than the Nominal Trip Setpoint; otherwise, the channel shall be declared inoperable. The Nominal Trip Setpoints and the methodology used to determine the as-found test acceptance criteria band and the as-left setpoint tolerance band shall be specified in the Bases.

INSERT 2 except for Trip Functions 14.a and 14.b (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions).

RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 4 of 8)

Reactor Trip System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(')

14.

Steam Generator (SG) Water Level Low-Low )

(continued)

c.

Veoeeff-IV4 axe 44xeeiftftf

-4

-W -

£SR-3~-a~--

eslA SR+B149 2&9_._.P, d.Cnanen 12 4

X S 3.3.1.1 I

2. pcsi 9lA Presr 1)

SR 3.3.1.7 SR 3.3.1.10 eser-1,2 1

4

-SR 5-,14

-4Vessel AT-SR 343+49A' 23.9%i RT-PfA

d.

Containment 1,2 4

X SR 3.3.1.1 s5 2.0 psig Pressure -

SR 3.3.1.7 Environmental SR 3.3.1.10 Allowance SR 3.3.1.16 Modifier

15.

Not Used (a)

(I)

(n)

(0)

CWrer.2 The Allowable Value defines the limiting safety system setting'See the Bases for theATrip Setpoints.

The applicable MODES for these channels in Table 3.3.2-1 are more restrictive.

A t

are time delay c 240 tocondc. A4,,a-ore ji("l ra ln~c c/a-130 oconc 5/+

>4JIKj (continued)

CALLAWAY PLANT 3.3-20 Amendment No. 133

INSERT 2 except for Trip Functions 14.a and 14.b (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions).

RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 5 of 8)

Reactor Trip System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABL FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS E VALUE'3)

16.

Turbine Trip

a. Low Fluid

10) 3 0

SR 3.3.1.10 2 539.42 Oil Pressure SR 3.3.1.15 psig

b. Turbine 10 4

P SR 3.3.1.10 k1% open Stop Valve SR 3.3.1.15 Closure

17.

Safety Injection 1.2 2 trains Q

SR 3.3.1.14 NA (SI) Input from Engineered Safety Feature Actuation System (ESFAS)

18.

Reactor Trip System Interlocks

a. Intermediate 2"

2 S

SR 3.3.1.11 2 6E-i1 amp Range SR 3.3.1.13 Neutron Flux, P-6

b. Low Power 1

1 pertrain T

SR 3.3.1.5 NA Reactor Trips Block, P-7

c.

Power 1

4 T

SR 3.3.1.11 s51.3%

Range SR 3.3.1.13 RTP Neutron Flux, P-8

d. Power 1

4 T

SR 3.3.1.11 s53.3%

Range SR 3.3.1.13 RTP Neutron Flux, P-9 (continued)

-ZLWE/RV.2 (a) The Allowable Value defines the limiting safety system settinWSee the Bases for theTrip Setpoints.

(e) Below the P-6 (Intermediate Range Neutron Flux) interlock.

(j)

Above the P-9 (Power Range Neutron Flux) interlock.

NO CALLAWAY PLANT 3.3-21 Amendment No. 133

INSERT 2 except for Trip Functions 14.a and 14.b (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions).

RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 6 of 8)

Reactor Trip System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a,

18.

ReactorTrip System Interlocks (continued)

e.

Power Range 1,2 4

S SR 3.3.1.11 2Ž6.7% RTP Neutron Flux, SR 3.3.1.13 and P-10 s 12.4% RTP

f.

Turbine 1

2 T

SR 3.3.1.10 s 12.4%

Impulse SR 3.3.1.13 turbine power

Pressure, P-1 3

19.

Reactor Trip 1,2 2 trains R

SR 3.3.1.4 NA Breakers (RTBs)'k) 3(b) 4(b) 5(b) 2 trains C

SR 3.3.1.4 NA

20.

Reactor Trip 1,2 1 each per U

SR 3.3.1.4 NA Breaker RTB Undervoltage and Shunt Trip 3(b) 4(b) 5(b) 1 each per C

SR 3.3.1.4 NA Mechanisms')

RTB

21.

AutomaticTrip 1,2 2 trains Q

SR 3.3.1.5 NA Logic 5gb) 3(b.4b)5 2 trains C

SR 3.3.1.5 NA (a)

(b)

(k)

The Allowable Value defines the limiting safety system settin;eeea secior the Trip Setpoints.

With Rod Control System capable of rod withdrawal or one or more rods not fully ins ed.

Including any reactor trip bypass breakers that are racked in and closed for bypassi g an RTB.

L 4 ' M/0hSa /

CALLAWAY PLANT 3.3-22 Amendment No. 133

INSERT 2 except for Trip Functions 14.a and 14.b (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions).

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 1 of 8)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE")

1.

Safety Injection

a. Manual Initiation

b. Automatic Actuation Logic and Actuation Relays (SSPS)

c.

Containment Pressure -

High 1

d.

Pressurizer Pressure -

Low 1,2.3.4 1.2.3.4 1.2.3 1,203) 2 2 trains 3

4 B

SR 3.3.2.8 C

SR 3.3.2.2 SR 3.3.2.4 SR 3.3.2.6 SR 3.3.2.13 D

SR 3.3.2.1 SR 3.3.2.5 SR 3.3.2.9 SR 3.3.2.10 D

SR 3.3.2.1 SR 3.3.2.5 SR 3.3.2.9 SR 3.3.2.10 NA NA s 4.5 psig

Ž 1834 psig

e.

Steam Line Pressure -

Low 1,2,3(b) 3 per steam line D

SR 3.3.2.1 SR 3.3.2.5 SR 3.3.2.9 SR 3.3.2.10 2 610 psigc) 's)

I

2.

Containment Spray

a. Manual Initiation

b. Automatic Actuation Logic and Actuation Relays (SSPS)

c.

Containment Pressure High - 3 1.2.3.4 1,2.3,4 1,2.3 2 per train, 2 trains 2 trains 4

B SR 3.3.2.8 C

SR 3.3.2.2 SR 3.3.2.4 SR 3.3.2.6 E

SR 3.3.2.1 SR 3.3.2.5 SR 3.3.2.9 SR 3.3.2.10 NA NA s 28.3 psig (continued)

I W

/

V T

No"uI

\\

r1 (a) The Allowable Value defines the limiting safety system settingvSee the Bases for thet¶rip Setpoints.

(b) Above the P-1I (Pressurizer Pressure) interlock and below P-11 unless the Function is blocked.

(c) Time constants used in the lead/lag controller are l 2: 50 seconds and r2 S 5 seconds.

(s) l c

a noun wd wa n a cu 3 se ponu be sddalr lb

{trip ont sha rbestor owithin th

-ef calibr olerance Bron eit de oft orr I

~ A I ~ ~, ' 7 - /

INSERT 1

1. If the as-found instrument channel setpoint is conservative with respect to the Allowable Value, but outside its as-found test acceptance criteria band, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. If the as-found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.

2. The instrument channel setpoint shall be reset to a value that is within the as-left setpoint tolerance band on either side of the Nominal Trip Setpoint, or to a value that is more conservative than the Nominal Trip Setpoint; otherwise, the channel shall be declared inoperable. The Nominal Trip Setpoints and the methodology used to determine the as-found test acceptance criteria band and the as-left setpoint tolerance band shall be specified in the Bases.

INSERT 3 except for Functions 1.e, 4.e.(1), 5.c, 5.e.(1), 5.e.(2), 6.d.(1), and 6.d.(2) (the Nominal Trip Setpoint defines the limiting safety system setting for these Functions).

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 2 of 8)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUEDa)

3.

Containment Isolation

a.

PhaseA Isolation (1) Manual 1,2,3,4 2

B SR 3.3.2.8 NA Initiation (2) Automatic 1,2,3.4 2 trains C

SR 3.3.2.2 NA Actuation SR 3.3.2.4 Logic and SR 3.3.2.6 Actuation SR 3.3.2.13 Relays (SSPS)

(3) Safety Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

Injection

b.

Phase B Isolation (1) Manual 1,2,3,4 2 per train, B

SR 3.3.2.8 NA Initiation 2 trains (2) Automatic 1,2,3.4 2 trains C

SR 3.3.2.2 NA Actuation SR 3.3.2.4 Logic and SR 3.3.2.6 Actuation Relays (SSPS)

(3) Contain-1,2,3 4

E SR 3.3.2.1 s 28.3 psig ment SR 3.3.2.5 Pressure SR 3.3.2.9 High - 3 SR 3.3.2.10 Easer (continued)

(a) The Allowable Value defines the limiting safety system setting.4Bee the Bases for theTrip Setpoints.

No m

/l CALLAWAY PLANT 3.3-39 Amendment No. 165 l

INSERT 3 except for Functions 1.e, 4.e.(1), 5.c, 5.e.(1), 5.e.(2), 6.d.(1), and 6.d.(2) (the Nominal Trip Setpoint defines the limiting safety system setting for these Functions).

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 3 of 8)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE'(a

4. Steam Line Isolation

a. Manual Initiation

12) 3°)

2 F

SR 3.3.2.8 NA

b. Automatic 1 2 3")

2 trains G

SR 3.3.2.2 NA Actuation Logic SR 3.3.2.4 and Actuation SR 3.3.2.6 Relays (SSPS)

c. Automatic 1, 2"T)36" 2 trainsto)

S SR 3.3.2.3 NA Actuation Logic and Actuation Relays (MSFIS)

d. Containment 1,21p) 3" 3

D SR 3.3.2.1 s 18.3 psig Pressure - High 2 SR 3.3.2.5 SR 3.3.2.9 SR 3.3.2.10

e. Steam Line Pressure (1) Low 1,2 i' 3°'7 3per steam D

SR 3.3.2.1 2610psig(c)(S) line SR 3.3.2.5 SR 3.3.2.9 SR 3.3.2.10 (2) Negative 3(2)(i) 3 per steam D

SR 3.3.2.1 s 124 psi'h)

Rate - High line SR 3.3.2.5 SR 3.3.2.9 SR 3.3.2.10 A

(continued)

I (a) The Allowable Value defines the limiting safety system settingV See the Bases for the~rrip Setpoints.

(b) Above the P-11 (Pressurizer Pressure) Interlock and below P-11 unless the Function is blocked.

(c)

Time constants used in the lead/lag controller are rI > 50 seconds and T2 S 5 seconds.

(g) Below the P-11 (Pressurizer Pressure) Interlock; however, may be blocked below P-11 when safety injection on low steam line pressure is not blocked.

(h) Time constant utilized in the rate/lag controller is 2 50 seconds.

(i)

Except when all MSIVs are closed.

(o) Each train requires a minimum of two pr rammable logic controllers to be OPERABLE.

(s) ann rip se va anne

{ tri mnt shall be r ed to wit eas-left ion toler and on eit e of th minal T epo stablished ia dance wit plant setp methodologo protect thI Iei analv mit.

• ZA/JSR- - /

CALLAWAY PLANT

.3.3-40 Amendment No. ###

INSERT 1

1. If the as-found instrument channel setpoint is conservative with respect to the Allowable Value, but outside its as-found test acceptance criteria band, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. If the as-found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.

2. The instrument channel setpoint shall be reset to a value that is within the as-left setpoint tolerance band on either side of the Nominal Trip Setpoint, or to a value that is more conservative than the'Nominal Trip Setpoint; otherwise, the channel shall be declared inoperable. The Nominal Trip Setpoints and the methodology used to determine the as-found test acceptance criteria band and the as-left setpoint tolerance band shall be specified in the Bases.

INSERT 3 except for Functions 1.e, 4.e.(1), 5.c, 5.e.(1), 5.e.(2), 6.d.(1), and 6.d.(2) (the Nominal Trip Setpoint defines the limiting safety system setting for these Functions).

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 4 of 8)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUEMa)

5. Turbine Trip and Feedwater Isolation

a. Automatic

,20). 30) 2 trains G

SR 3.3.2.2 NA Actuation Logic SR 3.3.2.4 and Actuation SR 3.3.2.6 Relays (SSPS)

SR 3.3.2.14

b. Automatic 1, 26, 30 2 trains(O)

S SR 3.3.2.3 NA Actuation Logic and Actuation Relays (MSFIS)

c. SG Water Level -

1,26' 4 per SG I

SR 3.3.2.1 s 91.4%") of High High (P-14)

SR 3.3.2.5 Narrow Range SR 3.3.2.9 Instrument SR 3.3.2.10 Span

d. Safety Injection Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

e. Steam Generator Water Level Low-Lowtq)

(1) Steam 1,2), 36) 4 perSG D

SR 3.3.2.1 2:20.6%') of Generator SR 3.3.2.5 Narrow Range Water Level SR 3.3.2.9 Instrument Low-Low SR 3.3.2.10 Span (Adverse Containment Environment)

(continued)

I l1 (a)

(i)

(o)

(q)

(s) lV y~-r/.

N A

/

The Allowable Value defines the limiting safety system settingWee the Bases for the'rrip Setpoints.

Except when all MFIVs are closed.

Each train requires a minimum of two programmable logic controllers to be OPERABLE.

Feedwater isolation only.

I u _W I

libratiqoklence ba trip s shall be~

d to wit as-le ration tole bandR peitter side of on sed in rdance i eplant t meth to prote esafety an s limit. /

-I Ja-A f~t-r-I CALLAWAY PLANT 3.3-41 Amendment No. ###

INSERT 1

1. If the as-found instrument channel setpoint is conservative with respect to the Allowable Value, but outside its as-found test acceptance criteria band, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. If the as-found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.

2. The instrument channel setpoint shall be reset to a value that is within the as-left setpoint tolerance band on either side of the Nominal Trip Setpoint, or to a value that is more conservative than the Nominal Trip Setpoint; otherwise, the channel shall be declared inoperable. The Nominal Trip Setpoints and the methodology used to determine the as-found test acceptance criteria band and the as-left setpoint tolerance band shall be specified in the Bases.

INSERT 3 except for Functions 1.e, 4.e.(1), 5.c, 5.e.(1), 5.e.(2), 6.d.(1), and 6.d.(2) (the Nominal Trip Setpoint defines the limiting safety system setting for these Functions).

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 5 of 8)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE'a)

5. Turbine Trip and Feedwater Isolation

e. Steam Generator Water Level Low-Low"')

(continued)

(2)

Steam Generator 1"r). 20'), 36 4 per SG D

SR 3.3.2.1 2 16.6%s of Water Level SR 3.3.2.5 Narrow Range Low-Low (Normal SR 3.3.2.9 Instrument Containment SR 3.3.2.10 Span Environment)

(3) Not used.

(4) Containment 1, 2a, 341 4

N SR 3.3.2.1 s 2.0 psig Pressure -

SR 3.3.2.5 Environmental SR 3.3.2.9 Allowance Modifier SR 3.3.2.10 (continued)

(a) a)

(k)

(I)

(q)

(r)

(s) 2J2vjERAr3 The Allowable Value defines the limiting safety system settingvtee the Bases for theATrip Setpoints.

Except when all MFIVs are closed.

Not used.

tMorn i^ l Not used.

Feedwater isolation only.

Except when the Containment Pressure - Environmental Allowance Modifier channels in the same protection sets are zA/z.rA

/

CALLAWAY PLANT 3.3-42 Amendment No. ###

INSERT 1

1. If the as-found instrument channel setpoint is conservative with respect to the Allowable Value, but outside its as-found test acceptance criteria band, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. If the as-found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.

2. The instrument channel setpoint shall be reset to a value that is within the as-left setpoint tolerance band on either side of the Nominal Trip Setpoint, or to a value that is more conservative than the Nominal Trip Setpoint; otherwise, the channel shall be declared inoperable. The Nominal Trip Setpoints and the methodology used to determine the as-found test acceptance criteria band and the as-left setpoint tolerance band shall be specified in the Bases.

INSERT 3 except for Functions 1.e, 4.e.(1), 5.c, 5.e.(1), 5.e.(2), 6.d.(1), and 6.d.(2) (the Nominal Trip Setpoint defines the limiting safety system setting for these Functions).

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 6 of 8)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION SPECIFIED CHANNELS CONDITIONS REQUIREMENTS VALUE1a)

CONDITIONS

6. Auxiliary Feedwater

a. Manual Initiation 1, 2, 3 I/pump P

SR 3.3.2.8 NA

b. Automatic 1,2,3 2 trains G

SR 3.3.2.2 NA Actuation Logic SR 3.3.2.4 and Actuation SR 3.3.2.6 Relays (SSPS)

c. Automatic 1,2,3 2 trains Q

SR 3.3.2.3 NA Actuation Logic and Actuation Relays (BOP ESFAS)

d. SG Water Level Low-Low (1) Steam 1.2,3 4 per SG D

SR 3.3.2.1 20.6%' of Generator SR 3.3.2.5 Narrow Range Water Level SR 3.3.2.9 Instrument Low-Low SR 3.3.2.10 Span (Adverse Containment Environment)

(2) Steam 1(r) 2(r) 3(r) 4 per SG D

SR 3.3.2.1 2 16.6%'s of Generator SR 3.3.2.5 Narrow Range Water Level SR 3.3.2.9 Instrument Low-Low SR 3.3.2.10 Span (Normal Containment Environment)

(continued)

I I

(a)

(r)

(s)

/V$CeAr

/. Nmr- /

The Allowable Value defines the limiting safety system setting/See the Bases for theY'rip Setpoints.

Except when the Containment Pressure - Environmental Allowance Modifier channels in the same protection sets are

.I CALLAWAY PLANT 3.343 Amendment No. ###

INSERT 1

1. If the as-found instrument channel setpoint is conservative with respect to the Allowable Value, but outside its as-found test acceptance criteria band, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. If the as-found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.

2. The instrument channel setpoint shall be reset to a value that is within the as-left setpoint tolerance band on either side of the Nominal Trip Setpoint, or to a value that is more conservative than the Nominal Trip Setpoint; otherwise, the channel shall be declared inoperable. The Nominal Trip Setpoints and the methodology used to determine the as-found test acceptance criteria band and the as-left setpoint-tolerance band shall be specified in the Bases.

INSERT 3 except for Functions 1.e, 4.e.(1), 5.c, 5.e.(1), 5.e.(2), 6.d.(1), and 6.d.(2) (the Nominal Trip Setpoint defines the limiting safety system setting for these Functions).

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 7 of 8)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION SPECIFIED CHANNELS CONDITIONS REQUIREMENTS VALUE(a)

CONDITIONS

6. Auxiliary Feedwater

d. SG Water Level Low-Low (continued)

(3) Veseli-AT 4

tinJ,

£e*e~

4Relaytp Nolanii

-4

&-Ra4...

En

-1 3.3.2.4

-cR-8 R-Be2 GR 8.3 2.9

_6

-~

^o.;4vo earo v44ef~44e I :U/0UNI

-4Ae9 qI_

iZ9n; =213

~4pewer.21- (4) Containment Pressure -

Environmental Allowance Modifier

e. Safety Injection

f. Loss of Offsite Power

g. Trip of all Main Feedwater Pumps 1 2,3 4

N SR 3.3.2.1 SR 3.3.2.5 SR 3.3.2.9 SR 3.3.2.10 s 2.0 psig Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

1,2,3 1.2 (n) 2 trains 2 per pump R

SR 3.3.2.7 SR 3.3.2.10 J

SR 3.3.2.8 NA NA (continued)

(a)

(k)

(I)

(n)

The Allowable Value defines the limiting safety system settingV See the Bases forp Trip Setpoints.

-i3th -tima delek: 240 seco A/#. '4 g4oo',

/

With a Git delay :9 1 BE)se e aFid-V04- &f.eed 0?,

nt Trip function may be blocked just before shutdown of the last operating main feedwater pump and restored just after the first main feedwater pump is put into service following performance of its startup trip test.

CALLAWAY PLANT 3.3-44 Amendment No. 165 1

INSERT 3 except for Functions 1.e, 4.e.(1), 5.c, 5.e.(1), 5.e.(2), 6.d.(1), and 6.d.(2) (the Nominal Trip Setpoint defines the limiting safety system setting for these Functions).

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 8 of 8)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION SPECIFIED CHANNELS CONDITIONS REQUIREMENTS VALUESa)

CONDITIONS

6. Auxiliary Feedwater (continued)

h. Auxiliary Feedwater Pump Suction Transfer on Suction Pressure - Low 1,2,3 3

0 SR 3.3.2.1 SR 3.3.2.9 SR 3.3.2.10 SR 3.3.2.12 2 20.64 psia

7. Automatic Switchover to Containment Sump

a. Automatic Actuation Logic and Actuation Relays (SSPS)

b. Refueling Water Storage Tank (RWST) Level -

Low Low Coincident with Safety Injection 1.2,3,4 1,2.3,4 2 trains 4

C SR 3.3.2.2 SR 3.3.2.4 SR 3.3.2.13 K

SR 3.3.2.1 SR 3.3.2.5 SR 3.3.2.9 SR 3.3.2.10 NA 2 35.2%

Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

8. ESFAS Interlocks

a. Reactor Trip, P-4

b. Pressurizer Pressure, P-11 1.2,3 1,2,3 2 per train, 2 trains 3

F SR 3.3.2.11 L

SR 3.3.2.5 SR 3.3.2.9 NA

• 1981 psig

9. Automatic Pressurizer PORV Actuation

a. Automatic Actuation Logic and Actuation Relays (SSPS) 1,2,3 2 trains H

SR 3.3.2.2 SR 3.3.2.4 SR 3.3.2.14 NA

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

D SR 3.3.2.1 SR 3.3.2.5 SR 3.3.2.9 s2350 psig (a)

The Allowable Value defines the limiting safety system settingY See the Bases for the Trip Setpoints.

A

/Vim;.,. /

CALLAWAY PLANT 3.3-45 Amendment No. 165 l

INSERT 3 except for Functions 1.e, 4.e.(1), 5.c, 5.e.(1), 5.e.(2), 6.d.(1), and 6.d.(2) (the Nominal Trip Setpoint defines the limiting safety system setting for these Functions).

ATTACHMENT 2 RETYPED TECHNICAL SPECIFICATIONS

RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 1 of 8)

Reactor Trip System Instnrmentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)

1.

Manual Reactor 1,2 2

B SR 3.3.1.14 NA Trip 3b), 4(b), 5()

2 C

SR 3.3.1.14 NA

2.

Power Range Neutron Flux

a.

High 1,2 4

D SR 3.3.1.1

• 112.3% RTP SR 3.3.1.2 SR 3.3.1.7 SR 3.3.1.11 SR 3.3.1.16

b. Low 1(c),2 4

E SR 3.3.1.1 s28.3% RTP SR 3.3.1.8 SR 3.3.1.11 SR 3.3.1.16

3.

Power Range 1,2 4

E SR 3.3.1.7 s 6.3 % RTP Neutron Flux SR 3.3.1.11 with time Rate - High SR 3.3.1.16 constant Positive Rate

> 2 sec

4.

Intermediate 1(c) 2(d) 2 F, G SR 3.3.1.1 5 35.3% RTP Range Neutron SR 3.3.1.8 Flux SR 3.3.1.11 (a) The Allowable Value defines the limiting safety system setting except for Trip Functions 14.a and 14.b (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions). See the Bases for the Nominal Trip Setpoints.

(b) With Rod Control System capable of rod withdrawal or one or more rods not fully Inserted.

(c)

Below the P-10 (Power Range Neutron Flux) Interlock.

(d) Above the P-6 (Intermediate Range Neutron Flux) interlock.

I CALLAWAY PLANT 3.3-1 7 Amendment No. ###

RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 2 of 8)

Reactor Trip System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE13)

5.

Source Range 2'e) 2 1, 4 SR 3.3.1.1 s 1.6 E5 cps Neutron Flux SR 3.3.1.8 SR 3.3.1.11 3(b),4(b), 5(u) 2 J, K SR 3.3.1.1 1.6 E5 cps SR 3.3.1.7 SR 3.3.1.11

6.

Overtemperature 1,2 4

E SR 3.3.1.1 Refer to Note 1 AT SR 3.3.1.3 (Page 3.3-23)

SR 3.3.1.6 SR 3.3.1.7 SR 3.3.1.10 SR 3.3.1.16

7.

OverpowerAT 1,2 4

E SR 3.3.1.1 Refer to Note 2 SR 3.3.1.7 (Page 3.3-24)

SR 3.3.1.10 SR 3.3.1.16

8.

Pressurizer Pressure

a.

Low 19 4

M SR 3.3.1.1 Z 1874 psig SR 3.3.1.7 SR 3.3.1.10 SR 3.3.1.16

b. High 1,2 4

E SR 3.3.1.1

s 2393 psig SR 3.3.1.7 SR 3.3.1.10 SR 3.3.1.16 (a) The Allowable Value defines the limiting safety system setting except for Trip Functions 14.a and 14.b (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions). See the Bases for the Nominal Trip Setpoints.

(b)

With Rod Control System capable of rod withdrawal or one or more rods not fully inserted.

(e)

Below the P-6 (Intermediate Range Neutron Flux) interlock.

(g)

Above the P-7 (Low Power Reactor Trips Block) interlock.

CALLAWAY PLANT 3.3-1 8 Amendment No. ###

RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 3 of 8)

Reactor Trip System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(')

9.

Pressurizer Water 1(g) 3 M

SR 3.3.1.1 s93.8%of Level - High SR 3.3.1.7 instrument SR 3.3.1.10 span

10.

Reactor Coolant 1(g) 3perloop M

SR 3.3.1.1 288.8%of Flow - Low SR 3.3.1.7 indicated loop SR 3.3.1.10 flow SR 3.3.1.16

11.

Not Used

12.

Undervoltage 1(9) 2/bus M

SR 3.3.1.9

Ž 10105 Vac RCPs SR 3.3.1.10 SR 3.3.1.16

13.

Underfrequency 1(g) 2/bus M

SR 3.3.1.9 57.1 Hz RCPs SR 3.3.1.10 SR 3.3.1.16

14.

Steam Generator (SG) Water Level Low-Lowa)

a. Steam 1,2 4 per SG E

SR 3.3.1.1 2 20.6%(q) of Generator SR 3.3.1.7 Narrow Range Water Level SR 3.3.1.10 Instrument Low-Low SR 3.3.1.16 Span (Adverse Containment Environment)

(a) The Allowable Value defines the limiting safety system setting except for Trip Functions 14.a and 14.b (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions). See the Bases for the Nominal Trip Setpoints.

(g)

Above the P-7 (Low Power Reactor Trips Block) interlock.

(I)

The applicable MODES for these channels in Table 3.3.2-1 are more restrictive.

(m)

Not used.

(q) 1. If the as-found instrument channel setpoint is conservative with respect to the Allowable Value, but outside its as-found test acceptance criteria band, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. If the as-found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.

2. The instrument channel setpoint shall be reset to a value that is within the as-left setpoint tolerance band on either side of the Nominal Trip Setpoint, or to a value that is more conservative than the Nominal Trip Setpoint; otherwise, the channel shall be declared inoperable. The Nominal Trip Setpoints and the methodology used to determine the as-found test acceptance criteria band and the as-left setpoint tolerance band shall be specified in the Bases.

I CALLAWAY PLANT 3.3-1 9 Amendment No. ###

RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 4 of 8)

Reactor Trip System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)

14.

Steam Generator (SG) Water Level Low-LowP°

b. Steam 1(P),2(P) 4 per SG E

SR 3.3.1.1 2 16.6%(q) of Generator SR 3.3.1.7 Narrow Range Water Level SR 3.3.1.10 Instrument Low-Low SR 3.3.1.16 Span (Normal Containment Environment)

c.

Not used.

d.

Containment 1,2 4

X SR 3.3.1.1 s 2.0 psig Pressure -

SR 3.3.1.7 Environmental SR 3.3.1.10 Allowance SR 3.3.1.16 Modifier

15.

Not Used I

I (a) The Allowable Value defines the limiting safety system setting except for Trip Functions 14.a and 14.b (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions). See the Bases for the Nominal Trip Setpoints.

(I)

The applicable MODES for these channels In Table 3.3.2-1 are more restrictive.

(n) Not used.

(o)

Not used.

(p) Except when the Containment Pressure - Environmental Allowance Modifier channels in the same protection sets are tripped.

(q)

1. If the as-found Instrument channel setpoint Is conservative with respect to the Allowable Value, but outside its as-found test acceptance criteria band, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. If the as-found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.

2. The instrument channel setpoint shall be reset to a value that is within the as-left setpoint tolerance band on either side of the Nominal Trip Setpoint, or to a value that Is more conservative than the Nominal Trip Setpoint; otherwise, the channel shall be declared Inoperable. The Nominal Trip Setpoints and the methodology used to determine the as-found test acceptance criteria band and the as-left setpoint tolerance band shall be specified In the Bases.

CALLAWAY PLANT 3.3-20 Amendment No. ###

RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 5 of 8)

Reactor Trip System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)

16.

Turbine Trip

a.

Low Fluid Oil Pressure

b.

Turbine Stop Valve Closure

17.

Safety Injection (SI) Input from Engineered Safety Feature Actuation System (ESFAS)

Ia) ra) 1,2 3

4 2 trains 0

P a

SR 3.3.1.10 SR 3.3.1.15 SR 3.3.1.10 SR 3.3.1.15 SR 3.3.1.14 2 539.42 psig 2 1% open NA

18.

Reactor Trip System Interlocks

a.

Intermediate Range Neutron Flux, P-6

b.

Low Power Reactor Trips Block, P-7

c.

Power Range Neutron Flux, P-8 2 (e) 2 1

I 1 pertrain 4

S T

T SR 3.3.1.11 SR 3.3.1.13 SR 3.3.1.5 SR 3.3.1.11 SR 3.3.1.13 2 6E-11 amp NA s 51.3% RTP

d.

Power Range Neutron Flux, P-9 I

4 T

SR 3.3.1.11 SR 3.3.1.13 s 53.3% RTP (a)

The Allowable Value defines the limiting safety system setting except for Trip Functions 14.a and 14.b (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions). See the Bases for the Nominal Trip Setpoints.

(e)

Below the P-6 (Intermediate Range Neutron Flux) interlock.

0)

Above the P-9 (Power Range Neutron Flux) Interlock.

CALLAWAY PLANT 3.3-21 Amendment No. ###

RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 6 of 8)

Reactor Trip System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)

18.

Reactor Trip System Interlocks

e. Power Range 1,2 4

S SR 3.3.1.11 2 6.7% RTP Neutron Flux, SR 3.3.1.13 and P-10

• 12.4% RTP

f.

Turbine 1

2 T

SR 3.3.1.10 s 12.4%

Impulse SR 3.3.1.13 turbine power

Pressure, P-13

19.

ReactorTrip 1,2 2trains R

SR3.3.1.4 NA Breakers (RTBs)(k) 3(b) 4(b), 5(b) 2 trains C

SR 3.3.1.4 NA

20.

Reactor Trip 1,2 1 each per U

SR 3.3.1.4 NA Breaker RTB Undervoltage and Shunt Trip 3°, 4(b),

4 1 each per C

SR 3.3.1.4 NA Mechanisms~k RTB

21.

Automatic Trip 1,2 2 trains Q

SR 3.3.1.5 NA Logic 3(b), 4(b), 5(b) 2 trains C

SR 3.3.1.5 NA (a) The Allowable Value defines the limiting safety system setting except for Trip Functions 14.a and 14.b (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions). See the Bases for the Nominal Trip Setpoints.

(b)

With Rod Control System capable of rod withdrawal or one or more rods not fully Inserted.

(k)

Including any reactor trip bypass breakers that are racked in and closed for bypassing an RTB.

CALLAWAY PLANT 3.3-22 Amendment No. ###

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 1 of 8)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)

Safety Injection

a.

Manual Initiation

b.

Automatic Actuation Logic and Actuation Relays (SSPS)

c.

Containment Pressure -

High I

d.

Pressurizer Pressure -

Low 1,2,3.4 1,2,3,4 1,2,3 1,2,3b) 2 2 trains 3

4 B

SR 3.3.2.8 C

SR 3.3.2.2 SR 3.3.2.4 SR 3.3.2.6 SR 3.3.2.13 D

SR 3.3.2.1 SR 3.3.2.5 SR 3.3.2.9 SR 3.3.2.10 D

SR 3.3.2.1 SR 3.3.2.5 SR 3.3.2.9 SR 3.3.2.10 NA NA s 4.5 psig 2 1834 psig

e.

Steam Line Pressure -

Low 11,2,0°'

3 per steam line D

SR 3.3.2.1 SR 3.3.2.5 SR 3.3.2.9 SR 3.3.2.10 2 610 psig(c)(a)

I

2.

Containment Spray

a.

Manual Initiation

b.

Automatic Actuation Logic and Actuation Relays (SSPS) 1.2,3,4 1,2,3,4 2 per train, 2 trains 2 trains B

SR 3.3.2.8 C

SR 3.3.2.2 SR 3.3.2.4 SR 3.3.2.6 NA NA (a) The Allowable Value defines the limiting safety system setting except for Functions 1.e, 4.e.(1), 5.c, 5.e.(1), 5.e.(2),

6.d.(1), and 6.d.(2) (the Nominal Trip Setpoint defines the limiting safety system setting for these Functions). See the Bases for the Nominal Trip Setpoints.

(b) Above the P-11 (Pressurizer Pressure) Interlock and below P-11 unless the Function Is blocked.

(c) Time constants used In the lead/lag controller are -rt Ž 50 seconds and T2 S 5 seconds.

(s) 1. If the as-found instrument channel setpoint is conservative with respect to the Allowable Value, but outside its as-found test acceptance criteria band, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. If the as-found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.

2. The instrument channel setpoint shall be reset to a value that is within the as-left setpoint tolerance band on either side of the Nominal Trip Setpoint, or to a value that is more conservative than the Nominal Trip Setpoint; otherwise, the channel shall be declared inoperable. The Nominal Trip Setpoints and the methodology used to determine the as-found test acceptance criteria band and the as-left setpoint tolerance band shall be specified in the Bases.

CALLAWAY PLANT 3.3-38 Amendment No. ###

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 2 of 8)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)

2.

Containment Spray

c.

Containment Pressure High - 3 1,2,3 4

E SR 3.3.2.1 SR 3.3.2.5 SR 3.3.2.9 SR 3.3.2.10

• 28.3 psig

3.

Containment Isolation

a.

Phase A Isolation (1) Manual Initiation (2) Automatic Actuation Logic and Actuation Relays (SSPS)

(3) Safety Injection 1,2,3,4 1,2,3,4 2

2 trains B

SR 3.3.2.8 C

SR 3.3.2.2 SR 3.3.2.4 SR 3.3.2.6 SR 3.3.2.13 NA NA Refer to Function I (Safety Injection) for all initiation functions and requirements.

b.

Phase B Isolation (1) Manual Initiation (2) Automatic Actuation Logic and Actuation Relays (SSPS)

(3) Contain-ment Pressure High - 3 1,2,3,4 1.2,3,4 1,2,3 2 per train, 2 trains 2 trains 4

B SR 3.3.2.8 C

SR 3.3.2.2 SR 3.3.2.4 SR 3.3.2.6 E

SR 3.3.2.1 SR 3.3.2.5 SR 3.3.2.9 SR 3.3.2.10 NA NA

• 28.3 psig (a)

TheAllowable Value defines the limiting safety system setting except for Functions 1.e, 4.e.(1), 5.c, 5.e.(1), 5.e.(2),

6.d.(1), and 6.d.(2) (the Nominal Trip Setpoint defines the limiting safety system setting for these Functions). See the Bases for the Nominal Trip Setpoints.

CALLAWAY PLANT 3.3-39 Amendment No. ###

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 3 of 8)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a) 4.. Steam Line Isolation

a. Manual Initiation 1.20), 30) 2 F

SR 3.3.2.8 NA

b. Automatic 1,20), 30) 2 trains G

SR 3.3.2.2 NA Actuation Logic SR 3.3.2.4 and Actuation SR 3.3.2.6 Relays (SSPS)

c. Automatic 1, 20),30) 2 trains°o)

S SR 3.3.2.3 NA Actuation Logic and Actuation Relays (MSFIS)

d. Containment 1,20), 30) 3 D

SR 3.3.2.1 s 18.3 psig Pressure - High 2 SR 3.3.2.5 SR 3.3.2.9 SR 3.3.2.10

e. Steam Line Pressure (1) Low 1,2 C),3(b)O) 3persteam D

SR 3.3.2.1 2610psig(c)(5) line SR 3.3.2.5 SR 3.3.2.9 SR 3.3.2.10 (2) Negative 3(g° 3 per steam D

SR 3.3.2.1

• 124 psi(h)

Rate - High line SR 3.3.2.5 SR 3.3.2.9 SR 3.3.2.10 I

(a) The Allowable Value defines the limiting safety system setting except for Functions I.e. 4.e.(1), 5.c, 5.e.(1), 5.e.(2),

6.d.(1), and 6.d.(2) (the Nominal Trip Setpoint defines the limiting safety system setting for these Functions). See the Bases for the Nominal Trip Setpoints.

(b)

Above the P-11 (Pressurizer Pressure) Interlock and below P-1I unless the Function Is blocked.

(c)

Time constants used in the lead/lag controller are ti 2 50 seconds and T2

• 5 seconds.

(g) Below the P-11 (Pressurizer Pressure) Interlock; however, may be blocked below P-11 when safety injection on low steam line pressure is not blocked.

(h) Time constant utilized in the rateAag controller Is 2 50 seconds.

(i)

Except when all MSIVs are closed.

(o) Each train requires a minimum of two programmable logic controllers to be OPERABLE.

(s) 1. If the as-found instrument channel setpoint is conservative with respect to the Allowable Value, but outside its as-found test acceptance criteria band, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. If the as-found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.

2. The instrument channel setpoint shall be reset to a value that is within the as-left setpoint tolerance band on either side of the Nominal Trip Setpoint, or to a value that is more conservative than the Nominal Trip Setpoint; otherwise, the channel shall be declared inoperable. The Nominal Trip Setpoints and the methodology used to determine the as-found test acceptance criteria band and the as-left setpoint tolerance band shall be specified in the Bases.

CALLAWAY PLANT 3.3-40 Amendment No. ###

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 4 of 8)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)

5. Turbine Trip and Feedwater Isolation

a. Automatic 1,20), 30) 2 trains G

SR 3.3.2.2 NA Actuation Logic SR 3.3.2.4 and Actuation SR 3.3.2.6 Relays (SSPS)

SR 3.3.2.14

b. Automatic 1, 20) 30) 2 trains(o)

S SR 3.3.2.3 NA Actuation Logic and Actuation Relays (MSFIS)

c. SG Water Level -

1,20) 4 per SG I

SR 3.3.2.1 s 91.4%(5) of High High (P-14)

SR 3.3.2.5 Narrow Range SR 3.3.2.9 Instrument SR 3.3.2.10 Span

d. Safety Injection Refer to Function I (Safety Injection) for all initiation functions and requirements.

I (a) The Allowable Value defines the limiting safety system setting except for Functions I.e. 4.e.(1), 5.c, 5.e.(1), 5.e.(2),

6.d.(1), and 6.d.(2) (the Nominal Trip Setpoint defines the limiting safety system setting for these Functions). See the Bases for the Nominal Trip Setpoints.

()

Except when all MFIVs are closed.

(o) Each train requires a minimum of two programmable logic controllers to be OPERABLE.

(s) 1. If the as-found instrument channel setpoint is conservative with respect to the Allowable Value, but outside its as-found test acceptance criteria band, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. If the as-found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.

2. The instrument channel setpoint shall be reset to a value that is within the as-left setpoint tolerance band on either side of the Nominal Trip Setpoint, or to a value that is more conservative than the Nominal Trip Setpoint; otherwise, the channel shall be declared inoperable. The Nominal Trip Setpoints and the methodology used to determine the as-found test acceptance criteria band and the as-left setpoint tolerance band shall be specified in the Bases.

CALLAWAY PLANT 3.3-41 Amendment No. ###

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 5 of 8)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)

5. Turbine Trip and Feedwater Isolation

e. Steam Generator Water Level Low-Lowvq (1) Steam 1,20), 30 4 per SG D

SR 3.3.2.1 2 20.6%s) of Generator Water SR 3.3.2.5 Narrow Range Level Low-Low SR 3.3.2.9 Instrument (Adverse SR 3.3.2.10 Span Containment Environment)

(2)Steam 1 (r),20), 3U.r) 4 per SG D

SR 3.3.2.1 2 16.6%') of Generator Water SR 3.3.2.5 Narrow Range Level Low-Low SR 3.3.2.9 Instrument (Normal SR 3.3.2.10 Span Containment Environment)

(3) Not used.

(4) Containment 1, 20), 30) 4 N

SR 3.3.2.1

• 2.0 psig Pressure -

SR 3.3.2.5 Environmental SR 3.3.2.9 Allowance SR 3.3.2.10 Modifier I

(a) TheAllowable Value defines the limiting safetysystem setting except for Functions 1.e, 4.e.(1), 5.c, 5.e.(1), 5.e.(2),

6.d.(1), and 6.d.(2) (the Nominal Trip Setpoint defines the limiting safety system setting for these Functions). See the Bases for the Nominal Trip Setpoints.

()

Except when all MFIVs are closed.

(k)

Not used.

(I)

Not used.

(q)

Feedwater isolation only.

(r)

Except when the Containment Pressure - Environmental Allowance Modifier channels in the same protection sets are tripped.

(s)

1. If the as-found instrument channel setpoint is conservative with respect to the Allowable Value, but outside its as-found test acceptance criteria band, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. If the as-found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.

2. The instrument channel setpoint shall be reset to a value that is within the as-left setpoint tolerance band on either side of the Nominal Trip Setpoint, or to a value that is more conservative than the Nominal Trip Setpoint; otherwise, the channel shall be declared inoperable. The Nominal Trip Setpoints and the methodology used to determine the as-found test acceptance criteria band and the as-left setpoint tolerance band shall be specified in the Bases.

CALLAWAY PLANT 3.3-42 Amendment No. ###

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 6 of 8)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION SPECIFIED CHANNELS CONDITIONS REQUIREMENTS VALUE(')

CONDITIONS

6. Auxiliary Feedwater

a. Manual Initiation 1, 2, 3 1/pump P

SR 3.3.2.8 NA

b. Automatic 1,2,3 2 trains G

SR 3.3.2.2 NA Actuation Logic SR 3.3.2.4 and Actuation SR 3.3.2.6 Relays (SSPS)

c. Automatic 1,2,3 2 trains Q

SR 3.3.2.3 NA Actuation Logic and Actuation Relays (BOP ESFAS)

d. SG Water Level Low-Low (1) Steam

1. 2, 3 4 per SG D

SR 3.3.2.1 2 20.6%() of Generator SR 3.3.2.5 Narrow Range Water Level SR 3.3.2.9 Instrument Low-Low SR 3.3.2.10 Span (Adverse Containment Environment)

(2) Steam 1(r), 2(r), 3(r) 4 per SG D

SR 3.3.2.1 216.6%() of Generator SR 3.3.2.5 Narrow Range Water Level SR 3.3.2.9 Instrument Low-Low SR 3.3.2.10 Span (Normal Containment Environment)

(a) The Allowable Value defines the limiting safety system setting except for Functions 1.e, 4.e.(1), 5.c, 5.e.(1), 5.e.(2),

6.d.(1), and 6.d.(2) (the Nominal Trip Setpoint defines the limiting safety system setting for these Functions). See the Bases for the Nominal Trip Setpoints.

(r)

Except when the Containment Pressure - Environmental Allowance Modifier channels in the same protection sets are tripped.

(s)

1. If the as-found instrument channel setpoint is conservative with respect to the Allowable Value, but outside its as-found test acceptance criteria band, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. If the as-found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.

2. The instrument channel setpoint shall be reset to a value that is within the as-left setpoint tolerance band on either side of the Nominal Trip Setpoint, or to a value that is more conservative than the Nominal Trip Setpoint; otherwise, the channel shall be declared inoperable. The Nominal Trip Setpoints and the methodology used to determine the as-found test acceptance criteria band and the as-left setpoint tolerance band shall be specified in the Bases.

I CALLAWAY PLANT 3.3-43 Amendment No. ###

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 7 of 8)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION SPECIFIED CHANNELS CONDITIONS REQUIREMENTS VALUE(3)

CONDITIONS

6. Auxiliary Feedwater

d. SG Water Level Low-Low (3) Not used (4) Containment

1. 2. 3 4

N SR 3.3.2.1

• 2.0 psig Pressure -

SR 3.3.2.5 Environmental SR 3.3.2.9 Allowance SR 3.3.2.10 Modifier

e. Safety Injection Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

f. Loss of Offsite 1,2.3 2 trains R

SR 3.3.2.7 NA Power SR 3.3.2.10

g. Trip of all Main 1,2(n) 2 per pump J

SR 3.3.2.8 NA Feedwater Pumps

h. Auxiliary 1,2,3 3

0 SR 3.3.2.1 2 20.64 psia Feedwater Pump SR 3.3.2.9 Suction Transfer SR 3.3.2.10 on Suction SR 3.3.2.12 Pressure - Low (a)

The Allowable Value defines the limiting safety system setting except for Functions 1.e, 4.e.(1), 5.c, 5.e.(1), 5.e.(2),

6.d.(1), and 6.d.(2) (the Nominal Trip Setpoint defines the limiting safety system setting for these Functions). See the Bases for the Nominal Trip Setpoints.

(k)

Not used.

(I)

Not used.

(n) Trip function may be blocked just before shutdown of the last operating main feedwater pump and restored just after the first main feedwater pump is put into service following performance of its startup trip test.

CALLAWAY PLANT 3.3-44 Amendment No. ###

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 8 of 8)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER REQUIRED SURVEILLANCE ALLOWABLE FUNCTION SPECIFIED CHANNELS CONDITIONS REQUIREMENTS VALUE(a)

CONDITIONS

7. Automatic Switchover to Containment Sump

a. Automatic 1,2,3,4 2 trains C

SR 3.3.2.2 NA Actuation Logic SR 3.3.2.4 and Actuation SR 3.3.2.13 Relays (SSPS)

b. Refueling Water 1,2,3,4 4

K SR 3.3.2.1 2 35.2%

Storage Tank SR 3.3.2.5 (RWST) Level -

SR 3.3.2.9 Low Low SR 3.3.2.10 Coincident with Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

Safety Injection

8. ESFAS Interlocks

a. Reactor Trip, P-4 1,2,3 2 per train, F

SR 3.3.2.11 NA 2 trains

b. Pressurizer 1,2.3 3

L SR 3.3.2.5 s 1981 psig Pressure, P-11 SR 3.3.2.9

9. Automatic Pressurizer PORV Actuation

a. Automatic 1,2,3 2 trains H

SR 3.3.2.2 NA Actuation Logic SR 3.3.2.4 and Actuation SR 3.3.2.14 Relays (SSPS)

b. Pressurizer 1,2,3 4

D SR 3.3.2.1 s2350 psig Pressure - High SR 3.3.2.5 SR 3.3.2.9 (a)

The Allowable Value defines the limiting safety system setting except for Functions 1.e, 4.e.(1), 5.c, 5.e.(1), 5.e.(2),

6.d.(1), and 6.d.(2) (the Nominal Trip Setpoint defines the limiting safety system setting for these Functions). See the Bases for the Nominal Trip Setpoints.

CALLAWAY PLANT 3.3-45 Amendment No. ###

ATTACHMENT 3 PROPOSED TECHNICAL SPECIFICATION BASES CHANGES (for information only)

RTS Instrumentation B 3.3.1 B 3.3 INSTRUMENTATION B 3.3.1 Reactor Trip System (RTS) Instrumentation BASES BACKGROUND The RTS initiates a unit shutdown, based on the values of selected unit parameters, to protect against violating the core fuel design limits and Reactor Coolant System (RCS) pressure boundary during anticipated operational occurrences (AOOs) and to assist the'Engineered Safety Features (ESF) Systems in mitigating accidents.

The protection and monitoring systems have been designed to assure safe operation of the reactor. This is achieved by specifying limiting safety system settings (LSSS) in terms of parameters directly monitored by the RTS, as well as specifying LCOs on other reactor system parameters and equipment performance.

The LSSS, defined in this specification as the Allowable Values in conjunction with the LCOs, establish the threshold for protectiv system action to prevent exceeding acceptable limits during Design asis Accidents (DBAs).

=At( rEX.

During A0Os, which are those events expected to occur one or more times during the unit life, the acceptable limits are:

1.

The Departure from Nucleate Boiling Ratio (DNBR) shall be maintained above the DNBR limit;

2.

Fuel centerline melt shall not occur; and

3.

The RCS pressure Safety Limit (SL) of 2735 psig shall not be exceeded.

Operation within the SLs of Specification 2.0, "Safety Limits (SLs)," also maintains the above values and assures that offsite dose will be within the 10 CFR 50 and 10 CFR 100 criteria during A0Os.

Accidents are events that are analyzed even though they are not expected to occur during the unit life. The acceptable limit during accidents is that offsite dose shall be maintained within an acceptable fraction of 10 CFR 100 limits. Different accident categories are allowed a different fraction of these limits, based on probability of occurrence.

(continued)

CALLAWAY PLANT B 3.3.1 -1 Revision 0

INSERT B 3.3.1-1 except for Trip Functions 14.a and 14.b in Technical Specification Table 3.3.1-1 (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions),

RTS Instrumentation B 3.3.1 BASES BACKGROUND Meeting the acceptable dose limit for an accident category is considered (continued) having acceptable consequences for that event.

The RTS instrumentation is segmented into four distinct but interconnected modules as described in FSAR, Chapter 7 (Ref. 1), and as identified below:

1.

Field transmitters or process sensors: provide a measurable electronic signal based upon the physical characteristics of the parameter being measured;

2.

Signal Process Control and Protection System, including 7300 Process Protection System, Nuclear Instrumentation System (NIS), field contacts, and protection channel sets: provides signal conditioning, bistable setpoint comparison, process algorithm actuation, compatible electrical signal output to protection system devices, and control board/control room/miscellaneous indications;

3.

Solid State Protection System (SSPS), including input, logic, and output bays: initiates proper unit shutdown and/or ESF actuation in accordance with the defined logic, which is based on the bistable outputs from the signal process control and protection system; and

4.

Reactor trip switchgear, including reactor trip breakers (RTBs) and bypass breakers: provides the means to interrupt power to the control rod drive mechanisms (CRDMs) and allows the rod cluster control assemblies (RCCAs), or "rods," to fall into the core and shut down the reactor. The bypass breakers allow testing of the RTBs at power.

Field Transmitters or Sensors To meet the design demands for redundancy and reliability, more than one, and often as many as four, field transmitters or sensors are used to measure unit parameters. To account for the calibration tolerances and instrument drift, which are assumed to occur between calibrations, statistical allowances are provided in th Trip Setpoints and Allowable Values. The OPERABILITY of each transmitter or sensor can be evaluated when its "as found" calibratien data are compared against its documented acceptance criteria.

NOl r rh l (continued' CALLAWAY PLANT B 3.3.1 -2 Revision 0

RTS Instrumentation B-3.3.1 BASES A/I BACKGROUND I Trip Setpoints and Allowable Values (continued)

Nomfn /

TheIuip Setpoints are theaemimevalues at which the bistables are set.

Any bistable is considered to be property adjusted when the "as left" value is within the two-sided tolerance band fo~calibration accuracy0(typieelly-

.46 a

. -IeAck A/e9mron,/

A The'Trip Setpoints Isted in Table B 3.3.1-1 and used in the bistables are based on the ana al limits stated in Reference 2. The selection of

/\\/e-e i-trip Setpoints such that adequate protection is provided when all sensor and processin 'time delays are taken into account. To allow for calibration tolerances, strumentation uncertainties, instrument drift, and A AA -coveFe-environment err for those RTS channels that must function in harsh environments as d fined by 10 CFR 50.49 (Ref. 4), theAllowabte-

/01/n

/ 7hr-felue specified in Table.3.1-1 im.i tho o ftnying-Le-are Agoosmei /

conservatively adjusted with respect to the analytical l o

detailed description of the methodology used to calculate the4trip Setpoints, includin their explicit uncertainties, is provided in Reference 6.,The actua minal Trip Setpoint entered into the bistable is more tadservative than tablspecified by the Allowable Value to account tor cha s In random measurement errors detectable by a COTi as designed).

the measured seapoint does not exceed the Allowable alue table isTconsidered OPERABLE.

-v 4

7I-S-/

Serpoints in accordance with the Allowable Value ensure that design limits are not violated during AOOs (and that the consequences of DBAs will be acceptable, providing the unit is operated fri m within the LCOs at the onset of the AOO or DBA and the equipment functions as designed).

Note that in the accompanying LCO 3.3.1, the Allowable Values of Tablel3.3.1-ow are theLSSSt Teeps 3

base on the Mo.

aly

\\zaa/ r eRmdS.e +cz

.0 e

Ter -R;IhCa)

Eat chanoel of the proce sfcon cequipmend caree ein sutepp of verify that the signal or setpoint accuracy is within the specified allowance requirements. Once a designated channel is taken out of service for testing, a simulated signal is injected in place of the field instriment signal. The process equipment for the channel in test is then tested, verified, and calibrated. SRs for the channels are specified in the SRs; se-oton.inued)

The Allowable Values listed in Table 3.3.1 yare based on the c

methodology described in Reference 6, and reviewed in support of Amendments 15, 43, 57, 84, 102, and 125, which incorporates all of the known uncertainties applicable for each channel,The magnitudes of these uncertainties are factored into the determi Jton of eac ~Trip 1VM,01 Setpoint. All field sensors and signal processf euipment fYTl'ipeseA

/

4continued)

CALLAWAY PLANT B 3.3.14 I/

J Revision 4c

INSERT B 3.3.1 A MM.

/

The methodology used to calculate theYrrip Setpoints for Functions 1 4.a and 1 4.b in Table B 3.3.1-1 is described in Reference 17. This is the same basic square root sum of

.the squares (SRSS) methodology described in References 6 and 18 (Reference 18 was reviewed and approved by NRC in support of Callaway Amendment 125 dated April 13, 1998), but with the inclusion of refinements to better reflect plant calibration practices and equipment performance. These refinements include the incorporation of a sensor reference accuracy term to address repeatability effects when performing a single pass calibration (i.e., one up and one down pass at several points verifies linearity and hysteresis, but not repeatability). In addition, sensor and rack error terms for calibration accuracy and drift are grouped in the Channel Statistical Allowance equation with their dependent M&TE terms, then combined with the other independent error terms using the SRSS methodology.

INSERT B 3.3.1 B The Allowable Values for Functions 14.a and 14.b in the accompanying LCO are based on the Trip Setpoints and are determined by subtracting the rack calibration accuracy from t eTrip Setpoint.

( N MM;

RTS Instrumentation B 3.3.1 BASES A Io° 1 BACKGROUND Trip Setpoints and Allowable Values (continued) channels are assumed to operate within the allowances of these uncertainty magnitudes.

Solid State Protection System The SSPS equipment is used for the decision logic processing of outputs, from the signal processing equipment bistables. To meet the redundancy requirements, two trains of SSPS, each performing the same functions, are provided. If one train is taken out of service for maintenance or test purposes, the second train will provide reactor trip and/or ESF actuation for the unit. If both trains are taken out of service or placed in test, a reactor trip will result. Each train is packaged in its own cabinet for physical and electrical separation to satisfy separation and independence requirements. The system has been designed to trip in the event of a loss of power, directing the unit to a safe shutdown condition.

The SSPS performs the decision logic for actuating a reactor trip or ESF actuation, generates the electrical output signal that will initiate the required trip or actuation, and provides the status, permissive, and annunciator output signals to the main control room of the unit.

The bistable outputs from the signal processing equipment are sensed by the SSPS equipment and combined into logic matrices that represent combinations indicative of various unit upset and accident transients. If a required logic matrix combination is completed, the system will initiate a reactor trip or send actuation signals via master and slave relays to those components whose aggregate Function best serves to alleviate the condition and restore the unit to a safe condition. Examples are given in the Applicable Safety Analyses, LCO, and Applicability sections of this Bases.

Reactor Trip Switchpear The RTBs are in the electrical power supply line from the control rod drive motor generator set power supply to the CRDMs. Opening of the RTBs interrupts power to the CRDMs, which allows the shutdown rods and control rods to fall into the core by gravity. Each RTB is equipped with a bypass breaker to allow testing of the RTB while the unit is at power.

During normal operation the output from the SSPS is a voltage signal that energizes the undervoltage coils in the RTBs and bypass breakers, if in use. When the required logic matrix combination is completed, the SSPS (continued)

CALLAWAY PLANT B 3.3.1-5 Revision 5

RTS Instrumentation B 3.3.1 BASES (continued)

BACKGROUND Reactor Trip Switchqear (continued) output voltage signal is removed, the undervoltage coils are de-energized, the breaker trip lever is actuated by the de-energized undervoltage coil, and the RTBs and bypass breakers are tripped open. This allows the shutdown rods and control rods to fall into the core. In addition to the de-energization of the undervoltage coils, each reactor trip breaker is also equipped with an automatic shunt trip device that is energized to trip the breaker open upon receipt of a reactor trip signal from the SSPS. Either the undervoltage coil or the shunt trip mechanism is sufficient by itself, thus providing a diverse trip mechanism.

The decision logic matrix Functions are described in the functional diagrams included in Reference 1. In addition to the reactor trip or ESF, these diagrams also describe the various "permissive interlocks" that are associated with unit conditions.

Each train has a built in testing device that can test the decision logic matrix Functions and the actuation devices while the unit is at power.

When any one train is taken out of service for testing, the other train is capable of providing unit monitoring and protection until the testing has been completed. The testing device is semiautomatic to minimize testing time.

APPLICABLE The RTS functions to maintain the applicable Safety Limits during all SAFETY AQOs and mitigates the consequences of DBAs in all MODES in which

ANALYSES, the Rod Control System is capable of rod withdrawal or one or more rods LCO, AND are not fully inserted.

APPLICABILITY Each of the analyzed accidents and transients can be detected by one or more RTS Functions. The accident analysis described in Reference 2-takes credit for most RTS trip Functions. RTS trip Functions not specifically credited in the accident analysis are qualitatively credited in the safety analysis and the NRC staff approved licensing basis for the unit. These RTS trip Functions may provide protection for conditions that do not require dynamic transient analysis to demonstrate Function performance. They may also serve as backups to RTS trip Functions that were credited in the accident analysis.

The LCO requires all instrumentation performing an RTS Function, listed in Table 3.3.1-1 in the accompanying LCO, to be OPERABLE. Failure of any instrument renders the affected channel(s) inoperable and reduces the reliability of the affected Functions.A (continued)

CALLAWAY PLANT B 3:3.1-6 Revision 5

INSERT B 3.3.1-6 (page 1 of 2)

The Allowable Value column for Trip Functions 14.a, Steam Generator Water Level Low-Low (Adverse Containment Environment), and 14.b, Steam Generator Water Level Low-Low (Normal Containment Environment) in TS Table 3.3.1-1 is modified by two Notes. If the as-found instrument channel setpoint for either of these specific Trip Function's channels is found to be outside the two-sided as-found test acceptance criteria band on either side of the Nominal Trip Setpoint, even if the as-found setting is conservative with respect to the Allowable Value, Note 1 requires that an assessment of channel 2.

performance shall be performed prior to returning the channel to service. The evaluation of channel performance will verify that the channel will continue to behave in accordance with design basis assumptions. The purpose of the assessment is to ensure confidence in the channel performance prior to returning the channel to service. An initial assessment shall be performed by the technician performing the surveillance who will evaluate the channel's ability to maintain a stable setpoint within the calibration tolerance band. The return of this channel to service shall require the approval of on-shift supervision after a review of the surveillance test results and the technician's initial assessment.

In addition, the affected channel shall be addressed under the corrective action program, including that program's evaluation completion time requirements.

Note 2 requires the instrument channel setpoint for a channel in these Trip Functions to be reset to a value within the as-left setpoint tolerance band for that channel on either side of the Nominal Trip Setpoint, or to a value that is more conservative than the Nominal Trip Setpoint. One example of a situation where the latter was used is discussed in Amendment 157. The conservative direction is indicated by the direction of the inequality sign applied to the Nominal Trip Setpoint in Bases Table B 3.3.1-1. Setpoint restoration and post-test verification assure that the assumptions in the plant setpoint methodology (Reference 17) are satisfied in order to protect the safety analysis limits. Note 2 preserves the safety analysis limits. If the channel can not be reset to a value within its as-left setpoint tolerance band, or to a value that is more conservative than the Nominal Trip Setpoint if required based on plant conditions, the channel shall be declared inoperable and the applicable Required Actions are taken.

The methodology used to determine the as-found test acceptance criteria band and the as-left setpoint tolerance band is based on the square-root-sum-of-the-squares (SRSS) of the tolerances applicable to the instrument loop or sub-loop constituents being tested and is discussed in Reference 19.

For channels that have a history of proper performance, an out-of-tolerance condition may be a 5% statistical outlier which is to be expected for a setpoint methodology that is based on maintaining a 95% probability with a 95% confidence level of proper performance. If the channel performance evaluation demonstrates this to be the case, the as-found and as-left setpoint data will be trended and no further evaluation would be performed until the next CHANNEL OPERATIONAL TEST.

INSERT B 3.3.1-6 (page 2 of 2)

All as-found and as-left setpoint data for these specific Trip Functions obtained during CHANNEL OPERATIONAL TESTS shall be trended to demonstrate that the rack drift assumptions used in the plant setpoint methodology are valid. If the trending evaluation determines that a channel is performing inconsistent with the uncertainty allowances applicable to the periodic surveillance test being performed (e.g., whether it be a COT, CHANNEL CALIBRATION, etc.), the channel shall be evaluated under the corrective action program. If the channel is not capable of performing its specified safety function, it shall be declared inoperable.

, I

.. :>11 UI U I II UtdktLJI I

• B.3.3.1 BASES

/ 9 APPLICABLE

9.

Pressurizer Water Level -High (continued)

SAFETY J

ANALYSES, pressure overshoot due to level channel failure cannot cause the LCO, AND safety valve to lift before reactor high pressure trip.

APPLICABILITY In MODE 1, when there is a potential for overfilling the pressurizer, the Pressurizer Water Level - High trip must be OPERABLE. This trip Function is automatically enabled on increasing power by the P-7 interlock. On decreasing power, this trip Function is automatically blocked below P-7. Below the P-7 setpoint, transients that could raise the pressurizer water level will be slow and the operator will have sufficient time to evaluate unit conditions and take corrective actions.

10.

Reactor Coolant Flow - Low The Reactor Coolant Flow - Low trip Function ensures that protection is provided against violating the DNBR limit due to low flow in one or more RCS loops, while avoiding reactor trips due to normal variations in loop flow. Above the P-7 setpoint, the reactor trip on low flow in two or more RCS loops is automatically enabled. Above the P-8 setpoint, a loss of flow in any RCS loop will actuate a reactor trip. Each RCS loop has three flow detectors to monitor flow. The flow signals are not used for any control system input.

The LCO requires three Reactor Coolant Flow - Low channels per loop to be OPERABLE in MODE I above P-7 (two-out-of-three trip logic). The Trip Setpoint is 2 90% of 111mnih rc~J F4w (l1MMF I D6,CG0 gpm). me/fe

/ /OY In MODE I above the P-8 selpoint, a loss of flow in one RCS loop 3, i~?, / c could result in DNB conditions in the core because of the higher power level. In MODE I below the P-8 setpoint and above the P-7 selpoint, a loss of flow In two or more loops is required to actuate a reactor trip because of the lower power level and the greater margin to the design limit DNBR. Below the P-7 setpoint, all reactor trips on low flow are automatically blocked since there is insufficient heat production to generate DNB conditions.

11 Not used.

12.

Undervoltage Reactor Coolant Pumps The Undervoltage RCP reactor trip Function ensures that protection is provided against violating the DNBR limit due to a

.(continued)

CALLAWAY PLANT B 3.3.1-19 Revision 4c

INSERT B 3.3.1 C At the beginning of each cycle the plant will normalize the RCS flow transmitters during zero power, normal operating pressure, normal operating temperature (NOP/NOT) conditions such that they indicate at 100% flow in each respective loop. This normalization is then verified prior to exceeding 75% of RATED THERMAL POWER and again after reaching full power following a refueling outage when suitable plant conditions are established. The bistables for the low RCS flow trip function are calibrated separately to verify that they are set at the nominal trip setpoint of 90% of indicated loop flow. The nominal trip setpoint is based on the loop-specific normalized flow input (i.e., the indicated loop flow) from each of the three RCS flow transmitters per RCS loop.

K Hi Instrumentation

--- 3.3.1 BASES REFERENCES (continued)

6.

Callaway Selpoint Methodology Report, SNP (UE)-565 dated May 1, 1984.

7.

Callaway OLAmendment No.43 dated April 14, 1989.

8.

FSAR Section 16.3, Table 16.3-1

9.

WCAP-1 3632-P-A, Revision 2, "Elimination of Pressure Sensor Response Time Testing Requirements,' January 1996.

FSAR Table 15.0-4.

11 WCAP-922 4 7"Reactor Core Response to Excessive Secondary Steam Releases," Revision 1, 48n8Fe 10 -F A7 /f111.

12.

NRC Generic Letter 85-09 dated May 23, 1985.

13.

FSAR Section 15.1.1

14.

RFR - 18637A.

WCAP-14036-P-A, Revision 1, 'Elimination of Periodic Protection Channel Response Time Tests,- October 1998.

16.

FSAR Section 15.4.6.

,P-,'

1. Z-VeC-0-?7+2 a'-o4o feidru`7p a7, /s1fo,

/ V.

=1 -ZZ-60o01-.

CALLAWAY PLANT B 3.3.1-59 Revision 4c

ESFAS Instrumentation B 3.3.2 B 3.3 INSTRUMENTATION B 3.3.2 Engineered Safety Feature Actuation System (ESFAS) Instrumentation BASES BACKGROUND The ESFAS initiates necessary safety systems, based on the values of selected unit parameters, to protect against violating core design limits and the Reactor Coolant System (RCS) pressure boundary, and to mitigate accidents.

The ESFAS instrumentation is segmented into three distinct but interconnected modules as identified below:

Field transmitters or process sensors and instrumentation: provide a measurable electronic signal based on the physical characteristics of the parameter being measured; Signal processing equipment including 7300 Process Protection System, field contacts, and protection channel sets: provide signal conditioning, bistable setpoint comparison, process algorithm actuation, compatible electrical signal output to protection system devices, and control board/control room/miscellaneous indications; and Solid State Protection System (SSPS) including input, logic, and output bays and Balance of Plant (BOP) ESFAS circuitry: initiate the proper unit shutdown or engineered safety feature (ESF) actuation in accordance with the defined logic and based on the bistable outputs from the signal process control and protection system.

Field Transmitters or Sensors To meet the design demands for redundancy and reliability, more than one, and often as many as four, field transmitters or sensors are used to measure unit parameters. In many cases, field transmitters or sensors that input to the ESFAS are shared with the Reactor Trip System (RTS).

In some cases, the same channels also provide control system inputs. To account for calibration tolerances and instrument drift, which are assumed to occur between calibrations, statistical allowances are provided in the to,,>> jets/Trip Setpoint and Allowable Values. The OPERABILITY of each transmitter or sensor can be evaluated when its "as found" calibration data are compared against its documented acceptance criteria.

(continued)

CALLAWAY PLANT B 3.3.2-1 Revision 0

ESFAS Instrumentation B-33.2 BASES BACKGROUND Signal Processing Equipment (continued)

Generally, three or four channels of process control equipment are used for the signal processing of unit parameters measured by the field instruments. The process control equipment provides signal conditioning, comparable output signals for instruments located on the main control board, and comparison of measured Input signals with setpoints established by safety analyses. If the measured value of a unit parameter exceeds the predetermined setpoint, an output from a bistable is forwarded to the SSPS for decision evaluation. Channel separation is maintained up to and through the input bays. However, not all unit parameters require four channels of sensor measurement and signal processing. Some unit parameters provide input only to the SSPS, while others provide input to the SSPS, the main control board, the unit computer, and one or more control systems.

Generally, if a parameter is used only for input to the protection circuits, three channels with a two-out-of-three logic are sufficient to provide the required reliability and redundancy. If one channel fails in a direction that would not result in a partial Function trip, the Function is still OPERABLE with a two-out-of-two logic. If one channel fails such that a partial Function trip occurs, a trip will not occur and the Function is still OPERABLE with a one-out'of-two logic.

Generally, if a parameter is used for input to the SSPS and a control function, four channels with a two-out-of-four logic are sufficient to provide the required reliability and redundancy. The circuit must be able to withstand both an input failure to the control system, which may then require the protection function actuation, and-a single failure in the other channels providing the protection function actuation. Again, a single

'failure will neither cause nor prevent the protection function actuation.

These requirements are described in IEEE-279-1971 (Ref. 4). The actual number of channels required for each unit parameter is specified in Reference 2.

aons Sl / Trip Setpomts and Allowable Values The rip Setpoints are the Nemtine values at which the bistables are set.

Any bistable is considered to be property adjusted when the "as left" value is within the two-sided tolerance band for calibration accuracy fVmeely A

rnck a, ;

.(continued)

CALLAWAY PLANT B 3.3.2-2 Revision 0

ESFAS Instrumentation

-11B 3.3.'2- '-

BARE r~~~~

-;M

~

A F i" BACKGROUND 1

Tnp.olpots and lb Values (continued) ri1e~(tpoints listed i ble B 3.3.2-1 and used in the bistables are based on the analytical fins stated in Reference 3. The selection of A/o /---Ffiesgrip Setpoints is su that adequate protection is provided when all sensor and processing ti delays are taken into account. To allow for calibration tolerances, inst mentation uncertainties, instrument drift, and AarlA eyere'environment errofor those ESFAS channels that must function in harsh environments a defined by 10 CFR 50.49 (Ref. 5), theyAlewebe

/Vem;,47rf f

k pitaeespec;ied in Table 3.2-1 in the eoepmyi 16are A/P m 1a /

conservatively adjusted with respect to the analytica im detailed description of the methodologies used to calculate the`nrip Setpoints, including their explicit uncertainties, Is provided in Reference 6 The BOP methodology used for Function 6.h is a similar square-root-su f-sguares (SRSS) methodology as used for the RTS setpoints.

he actual

/bminal Trip Setpoint entered into the bistable is more cons ative than that specified by the Allowable Value to account for cha in random measurement errors detectable by a COT..

fIf the measured setpoint does not exceed the Allowa Value, the bistable is considered OPERABLE.

V= rR33AA Setpoints in accordance with the Allowable Value ensure that the consequences of Design Basis Accidents (DBAs) will be acceptable, providing the unit is operated from within the LCOs at the onset of the DBA and the equipment functions as designed.

Each channel can be tested on line to verify that the signal processing equipment and setpoint accuracy is within the specified allowance requirements. Once a designated channel is taken out of service for testing, a simulated signal is injected in place of the field instrument signal. The process equipment for the channel in test is then tested, verified, and calibrated. SFs for the channels are specified in the SR The Allowable Values listed in Table 3.3.2-1'are based on the methodologies described In Reference 6, which incorporate all of the known uncertainties applicable for each channel. The magnitudes of these uncertainties are factored into the determi tion of ea Trip All l

Setpoint. All field sensors and signal processin equipment for tnese channels are assumed to operate within the a wances of these uncertainty magnitudes.

(continued)

CALLAWAY PLANT B.3.3.2-3 Revision 4c 1

INSERT B 3.3.2 A NOM;,, /

The methodology used to calculate the9rrip Setpoints for Functions 1.e, 4.e.(1), 5.c, 5.e.(1), 5.e.(2), 6.d.(1), and 6.d.(2) in Table B 3.3.2-1 is described in Reference 18. This is the same basic square root sum of the squares (SRSS) methodology described in References 6 and 19 (Reference 19 was reviewed and approved by NRC in support of Callaway Amendment 125 dated April 13, 1998), but with the inclusion of refinements to better reflect plant calibration practices and equipment performance. These refinements include the incorporation of a sensor reference accuracy term to address repeatability effects when performing a single pass calibration (i.e., one up and one down pass at several points verifies linearity and hysteresis, but not repeatability). In addition, sensor and rack error terms for calibration accuracy and drift are grouped in the Channel Statistical Allowance equation with their dependent M&TE terms, then combined with the other independent error terms using the SRSS methodology.

INSERT B 3.3.2 B The Allowable Values for Functions 1.e, 4.e.(1), 5.c, 5.e.(1), 5.e.(2), 6.d.(1), and 6.d.(2) in the accompanying LCO are based on the Trip Setpoints and are determined by subtracting (for low setpoint trips) or adding for high setpoint trips) the rack calibration accuracyfrom/to the4TripSetpoint.

(_

,N morl~A I

ESFAS Instrumentation B 3.3.2 BASES BACKGROUND (continued)

Balance of Plant (BOP) ESFAS The BOP ESFAS processes signals from SSPS, signal processing equipment (e.g., LSELS), and plant radiation monitors to actuate certain ESF equipment. There are two redundant trains of BOP ESFAS (separation groups 1 and 4), and a third separation group (separation group 2) to actuate the Turbine Driven Auxiliary Feedwater pump and reposition automatic valves (turbine steam supply valves, turbine trip and throttle valve) as required. The separation group 2 BOP-ESFAS cabinet is considered to be part of the end device (the Turbine Driven Auxiliary Feedwater pump) and its OPERABILITY is addressed under LCO 3.7.5, "Auxiliary Feedwater (AFW) System." The redundant trains provide actuation for the Motor Driven Auxiliary Feedwater pumps (and reposition automatic valves as required, i.e., steam generator blowdown and sample line isolation valves, ESW supply valves, CST supply valves),

Containment Purge Isolation, Control Room Emergency Ventilation, and Emergency Exhaust Actuation functions.

The BOP ESFAS has a built-in automatic test insertion (ATI) feature which continuously tests the system logic. Any fault detected during the testing causes an alarm on the main control room overhead annunciator system to alert operators to the problem. Local indication shows the test step where the fault was detected.

APPLICABLE SAFETY

ANALYSES, LCO, AND APPLICABILITY Each of the analyzed accidents can be detected by one or more ESFAS Functions. One of the ESFAS Functions is the primary actuation signal for that accident. An ESFAS Function may be the primary actuation signal for more than one type of accident. An ESFAS Function may also be a secondary, or backup, actuation signal for one or more other accidents. For example, Pressurizer Pressure - Low is a primary actuation signal for small loss of coolant accidents (LOCAs) and a backup actuation signal for steam line breaks (SLBs) outside containment.

Functions such as manual initiation, not specifically credited in the accident safety analysis, are qualitatively credited. These Functions may -

provide protection for conditions that do not require dynamic transient analysis to demonstrate Function performance. These Functions may also serve as backups to Functions that were credited in the accident analysis (Ref. 3).

r-r

,,4

-? <o _

a I

x -

v U

.C. L as -

The LCO requires all instrumentation performing an ESFAS Functi n to be OPERABLE. Failure of any instrument renders the affected cl) nnel(s) 4poperable and reduces the reliability of the affected Functions.

rThe LCO generally requires OPERABILITY of three or four channels in each instrumentation function and two channels in each logic and manual C(-r e

initiation function. The two-out-of-three and the two-out-of-four Da rAd (oi e

l

°§ g(continued)

CALLAWAY PLANT B 3.3.2-5 Revision 5

INSERT B 3.3.2-5 (page 1 of 2)

The Allowable Value column for Functions 1.e (Safety Injection on Steam Line Pressure

- Low), 4.e.1 (Steam Line Isolation on Steam Line Pressure - Low), 5.c (Turbine Trip and Feedwater Isolation on Steam Generator Water Level High-High), 5.e.1 (Feedwater Isolation on Steam Generator Water Level Low-Low - Adverse Containment Environment), 5.e.2 (Feedwater Isolation on Steam Generator Water Level Low-Low -

Normal Containment Environment), 6.d.1 (Auxiliary Feedwater Actuation on Steam Generator Water Level Low-Low - Adverse Containment Environment), and 6.d.2 (Auxiliary Feedwater Actuation on Steam Generator Water Level Low-Low - Normal Containment Environment) in TS Table 3.3.2-1 is modified by two Notes. If the as-found instrument channel setpoint for any of these specific Function's channels is found to be outside the two-sided as-found test acceptance criteria band on either side of the Nominal Trip Setpoint, even if the as-found setting is conservative with respect to the Allowable Value, Note I requires that an assessment of channel performance shall be performed prior to returning the channel to service. The evaluation of channel performance will verify that the channel will continue to behave in accordance with design basis assumptions. The purpose of the assessment is to ensure confidence in the channel performance prior to returning the channel to service. An initial assessment shall be performed by the technician performing the surveillance who will evaluate the channel's ability to maintain a stable setpoint within the calibration tolerance band. The return of this channel to service shall require the approval of on-shift supervision after a review of the surveillance test results and the technician's initial assessment.

In addition, the affected channel shall be addressed under the corrective action program, including that program's evaluation completion time requirements.

Note 2 requires the instrument channel setpoint for a channel in these Functions to be reset to a value within the as-left setpoint tolerance band for that channel on either side of the Nominal Trip Setpoint, or to a value that is more conservative than the Nominal Trip Setpoint. One example of a situation where the latter was used is discussed in Amendment 157. The conservative direction is indicated by the direction of the inequality sign applied to the Nominal Trip Setpoint in Bases Table B 3.3.2-1. Setpoint restoration and post-test verification assure that the assumptions in the plant setpoint methodology (Reference 18) are satisfied in order to protect the safety analysis limits.

Note 2 preserves the safety analysis limits. If the channel can not be reset to a value within its as-left setpoint tolerance band, or to a value that is more conservative than the Nominal Trip Setpoint if required based on plant conditions, the channel shall be declared inoperable and the applicable Required Actions are taken. The methodology used to determine the as-found test acceptance criteria band and the as-left setpoint tolerance band is based on the square-root-sum-of-the-squares (SRSS) of the tolerances applicable to the instrument loop or sub-loop constituents being tested and is discussed in Reference 20.

INSERT B 3.3.2-5 (page 2 of 2)

For channels that have a history of proper performance, an out-of-tolerance condition may be a 5% statistical outlier which is to be expected for a setpoint methodology that is based on maintaining a 95% probability with a 95% confidence level of proper performance. If the channel performance evaluation demonstrates this to be the case, the as-found and as-left setpoint data will be trended and no further evaluation would be performed until the next CHANNEL OPERATIONAL TEST.

All as-found and as-left setpoint data for these specific Functions obtained during CHANNEL OPERATIONAL TESTS shall be trended to demonstrate that the rack drift assumptions used in the plant setpoint methodology are valid. If the trending evaluation determines that a channel is performing inconsistent with the uncertainty allowances applicable to the periodic surveillance test being performed (e.g.,-whether it be a COT, CHANNEL CALIBRATION, etc.), the channel shall be evaluated under the corrective action program. If the channel is not capable of performing its specified safety function, it shall be declared inoperable.

ESFAS Instrumentation B 3.3.2 BASES SURVEILLANCE REQUIREMENTS SR 3.3.2.12 (continued) opening the PORVs and depressurizing the RCS. If the PORV block valves are closed, there is not enough pressure to open the PORVs.

REFERENCES 1

2.

3.

4.

5.

6.

FSAR, Chapter 6.

FSAR, Chapter 7.

FSAR, Chapter 15.

IEEE-279-1971 10 CFR 50.49.

Callaway Setpoint Methodology Report (NSSS), SNP (UE)-565 dated May 1, 1984. and Callaway Instrument Loop Uncertainty Estimates (BOP), J-U-GEN.

7.

8.

9.

10.

12.

13.

14.

15.

16.

17.

Not used.

Callaway OLAmendment No. 64 dated October 9, 1991.

FSAR Section 16.3. Table 16.3-2.

WCAP-1 3632-P-A, Revision 2, "Elimination of Pressure Sensor Response Time Testing Requirements," January 1996.

Callaway OLAmendment No. 43 dated April 14, 1989.

SLNRC 84-0038 dated February 27, 1984.

Callaway OLAmendment No. 117 dated October 1, 1996.

WCAP-14036-P-A, Revision 1, "Elimination of Periodic Protection Channel Response Time Tests," October 1998.

FSAR, Section 15.5.1 FSAR, Section 15.6.1 Letter from Mel Gray (NRC) to Garry L Randolph (UE), *Revision 20 of the Inservice Testing Program for Callaway Plant, Unit 1 (TAC No. MA4469),3 dated March 19, 1999.

1.

//1, WIer-lfs4aie /e44*r OAP-04-9j dA4ado~ ACHYii+X7 CALLAWAYPLANT J9 11 i;2P""e7, J

Revision4c

20. Ale-7zz-oo1/-7*