Text

Amend 159 to License DPR-51,revising Operability Requirements for RPS & ESFAS
	ML20082F830
Person / Time
Site:	Arkansas Nuclear
Issue date:	04/03/1995
From:	Kalman G; NRC (Affiliation Not Assigned)
To:	;
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ML20082F835	List: ML20082F830; ML20082F836;
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	NUDOCS 9504120354
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p*ft:o UNITED STATES o

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.i NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20E66

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.ENTERGY OPERATIONS INC.

5 DOCKET NO. 50-313-ARKANSAS NVCLEAR ONE. UNIT NO. 1 AMENDMENT TO FACILITY OPERATING LICENSE Amendment No.159 License No. DPR-51 1.

The Nuclear Regulatory Comission (the Comission) has found that:

A.

The application for amendment by Entergy Operations, Inc. (the licensee) dated July 22, 1993, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act),

and the Commission's rules and regulations set forth in 10 CFR Chapter I; 8.

The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Comission; C.

There is reasonable assurance:

(i) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Comission's regulations; i

D.

The issuance of this license amendment will not be ' inimical to the l

common defense and security or to the health and safety of the public; and i

E.

The issuance of this amendment is in accordance with 10 CFR Part 51

)

of the Comission's regulations and all applicable requirements have been satisfied.

i i

9504120354 950403 PDR ADOCK 05000313 P

PDR l

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2.

Accordingly, the license is amended by changes to the Technical Specifications as indicated in the attachment to this license amendment, and Paragraph 2.C.(2) of Facility Operating License No. DPR-51-is hereby amended to read as follows:

i 2.

Technical Specifications 1

The Technical Specifications contained in Appendix' A, as revised-through Amendment No.159, are hereby incorporated in the license.

The licensee shall operate the facility in accordance with the Technical Specifications.

i 3.

The. license amendment is effective as of its date of issuance to be implemented within 30 days.

FOR THE NUCLEAR REGULATORY COMMISSION M-p

~.

George Kalman, Senior Project Manager Project Directorate IV-1 Division of Reactor Projects - III/IV Office of Nuclear Reactor Regulation

Attachment:

Changes to the Technical Specifications Date of Issuance:

April 3, 1995

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ATTACHMENT TO LICENSE AMENDMENT NO.159 FACILITY OPERATING LICENSE NO. DPR-51 DOCKET NO. 50-368 Replace the following pages of the Appendix "A" Technical Specifications with the attached pages.

The revised pages are identified by Amendment number and contain vertical lines indicating the area of change.

The corresponding overleaf pages are also provided to maintain document completeness.

REMOVE PAGES INSERT PAGES 3/4 3-2 3/4 3-2 3/4 3-3 3/4 3-3 3/4 3-5 3/4 3-5 3/4 3-5a 3/4 3-Sa 3/4 3-5b 3/4 3-Sc 3/4 3-7 3/4 3-7 3/4 3-11 3/4 3-11 3/4 3-11a 3/4 3-12 3/4 3-12 3/4 3-13 3/4 3-13 3/4 3-14 3/4 3-14 I

3/4 3-15 3/4 3-15 i

B 3/4 3-la 6-7 6-7

/

]NSTRUMENTATION AU#VffttANcf RESUIREMFWT1 (Centinuedi

4. 3.1.1. 5 The Core Protection Calculator system shall be determined OPERA 8LE at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months by verifying that less than three auto restarts have occurred on sach calculator during the past 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

4.3.3.1.6 The Core Protection Calculator Systes shall be subjected to a CHANNEL FUNCTIONAL TEST to verify CPERABILITY within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months of receipt of a valid High CPC Room Temperature alare.

ARKANSAS - UNIT 2 3/4 3-la Amendment No. N. 101

TABLE 3_3-1 REACTOR PROTECTIVE INSTRUMENTATION MINIMUM TOTAL NO.

CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIP QEERAELE MODES ACTION 1.

Manual Reactor Trip 2 sets of 2 1 set of 2 2 sets of 2

1. 2 5

2 sets of 2 I set of 2 2 sets of-2 3*.4*.5*

8 2.

Linear Power Level - High 4

2 3

1. 2 2.3 l

3.

Logarithmic Power Level-High a.

Startup and 4

2(a)(d) 3 2.3*.4* 5*

2.3 b.

Shutdown 4

0 2

3. 4. 5 4

4.

Pressurizer Pressure - High 4

2 3

1, 2 2.3 l

5.

Pressurtzer Pressure - Low 4

2(b) 3 1, 2.3* 4*.5*

2.3 l

6.

Containment Pressure - High 4

2 3

1. 2 2.3 l

7.

Steam Generator Pressure - Low 4/SG 2/SG 3/SG

1. 2.3*.4*.5*

2.3' l

8.

Steam Generator Level - Low 4/SG 2/SG 3/SG

1. 2 2.3 l

9.

Local Power Density - High 4

2(c)(d) 3 1, 2 2.3 l

t ARKANSAS - UNIT 2 3/4 3-2 Amendment No. 34. 444, 159

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e+1 TABLE 3.3-1 (Continuedl REACTOR PROTECTIVE INSTRUMENIAllDH MINIMUM TOTAL NO.

CHANNELS CHANNELS

~ APPLICABLE FUNCTIONAL UNIT OF CHANNFtS 10 TRIP OPERABLE M00FS At110N

10. DNBR - Low 4

2(c)(d) 3

1. 2 2.3 l

11. Steam Generator Level - High 4/SG 2/SG 3/SG 1.2 2.3 l

12. Reactor Protection System

'l~

Logic A. Matrix Logic 6

1 3

1.2 1

6 1

3 3*.4*.5*

8.

B. Initiation Logic 4

2 4

1.2 5

4 2

4 3*.4*.5*

8

13. Reactor Trip Breakers 4(f) 2 4

1. 2 5

4(f) 2 4

3*.4*.5*

8

14. Core Protection Calculators 4

2(c)(d) 3

.l.

2 2.3.7 l-

15. CEA Calculators 2

1 2(e)

1. 2-6.7 l

l l

.1

'l ARKANSAS - UNIT 2 3/4 3-3 Amendment No. 34.-144,159 l

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TABII 3.3-1 (Continued) p TABLE NOTATION

With the protective system trip breakers in the closed _ position and the CEA drive system capable of CEA withdrawal.

l Tripmaybe'manuallybypassedabove10"%ofRATEDTHERMALPOWEg (a)

by pass shall be automatically removed when THERMAL POWER is 5 10 RATED THERMAL POWER.

(b) Trip may be manually bypassed below 400 pala; bypass shall be automatically removed whenever pressurizer pressure is 2 500 psia.

(c) Trip may be manually bypassed below 10" % of RATED THERMAL POWERj4 bypass shall be automatically removed when THERMAL' POWER is 210 % of RATED THERMAL POWER. During testing pursuant to Special_ Test Exception 3.10.3, trip may be manually bypassed below 1% of RATED THERMAL POWER; bypass shall be automatically removed when THERMAL POWER is 2 1% of RATED THERMAL POWER.

(d) Trip may be bypassed during testing pursuant to Special Test Exception 3.10.3.

l

.(e) See Special Test Exception 3.10.2.

(f) Each channel shall be comprised of two trip breakers; actual trip logic shall be one-out-of-two taken twice.

ACTION STATEMENTS ACTION 1 -

With the number of channels OPERABLE one less than required by the Minimum Channels OPERABLE requirement, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and/or open the protective system trip broskers.

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ARKANSAS - UNIT 2 3/4 3-4 Amendment No. 134 l

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,h; TABLE 3.3-1 (Continued) l l

ACTION STATEMENTS l

-i ACTION 2 -

With the number'of' channels OPERABLE one less than the Total Number of l

Channels STARTUP and/or POWER OPERATION may' continue provided the inoperable channel. is 'placed in the bypa'ssed or tripped condition within - (

I hour.

If the inoperable channel'is bypassed for greater than 48-i n

hours..the desirability of maintaining ~this channel in-the bypassed j

condition shall be reviewed at the next regularly scheduled PSC meeting

' g in.accordance with Specification'6.5.1.7.n. The channel.'shall be:

returned to-OPERABLE status prior to startu'p 'Tollowing the-next COLD =

4 !

SHUTDOWN.

With a. channel process measurement circuit that affects multiple

~

functional units inoperable or in test, bypass or trip allTassociated functional units as listed below.

Process Measurement Circuit

. Functional' Unit Rvnassed-1.

Linear Power Linear Power Level High (Subchannel or Linear)

Local Power Density - High DNBR - Low Log Power Level.- High*

2.

Pressurizer Pressure - NR Pressurizer Pressure - High Local Power Density High DNBR - Low y

3.

Containment Pressure NR Containment Pressure - High (RPS)

Ji Containment Pressure High (ESFAS)

Containment Pressure High High ;

]

(ESFAS) 4 Steam Generator 1 Pressure Steam Generator 1 Pressure Low Steam Generator 1 AP.(EFAS 1) l Steam Generator 2 AP (EFAS 2)

~

S.

Steam Generator 2 Pressure Steam Generator 2 Pressure ' Low Steam Generator.1 AP (EFAS 1)

Steam Generator 2 AP (EFAS 2)

I 6.

Steam Generator 1 Level Steam Generator 1 Level - Low Steam Generator.1 Level - High l

Steam Generator 1 AP (EFAS 1) 7.

Steam Generator 2 Level Steam Generator 2 Level - Low Steam Generator-2 Level High Steam Generator 2 AP (EFAS 2) j 8.

Core Protection Calculator Local Power Density High DNBR - Low

-)

Only for failure common to both linear power and log power.

ARKANSAS UNIT 2 3/4 3 5 Amendment No.M,159

.]

ry TABLF 1.3 1 (Continued) 1 ACTION STATFMENTS ACTION 3 - With the number of channels OPERABLE one less than the Minimum Channels OPERABLE requirement. STARTUP and/or POWER OPERATION may continue provided the following conditions are satisfied:

a.

Verify that one of the inoperable channels has been bypassed and place the other inoperable channel in the tripped condition within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months , and b.

All functional units affected by the bypassed / tripped channel shall also be placed in the bypassed / tripped condition as listed below:

Process Measurement circuit Functional Unit Ryoassed/Trinned 1.

Linear Power Linear Power Level - High (Subchannel or Linear)

Local-Power Density High DNBR - Low Log Power Level High**

2.

Pressurizer Pressure NR Pressurizer Pressure High Local Power Density -High DNBR Low 3.

Containment Pressure NR Containment Pressure High (RPS)

Containment Pressure High (ESFAS)

Containment Pressure High High (ESFAS) 4.

Steam Generator 1 Pressure Steam Generator 1 Pressure - Low Steam Generator 1 AP (EFAS 1)

Steam Generator 2 AP (EFAS.2) 5.

Steam Generator 2 Pressure Steam Generator 2 Pressure Low Steam Generator 1 AP (EFAS 1)

Steam Generator 2 AP (EFAS 2)-

6.

Steam Generator 1 Level Steam Generator 1 Level Low Steam Generator 1 Level High Steam Generator 1 AP (EFAS 1) 7.

Steam Generator 2 Level Steam Generator 2 Level Low Steam Generator 2 Level - High Steam Generator 2 AP (EFAS 2) 8.

Core Protection Calculator Local Power Density - High DNBR - Low STARTUP and/or POWER OPERATION may continue until the performance nf the next required CHANNEL FUNCTIONAL TEST.

Subsequent STARTUP and/or POWER OPERATION may continue if one channel is restored to OPERABLE status and the provisions of ACTION 2 are satisfied.

- Only for failure or activities common to both linear power and log power.

1 ARKANSAS - UNIT 2 3/4 3 Se Amendment No. 159 i

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t-a' TAalF 3.3 1 (Continued) i

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ACTION STATFMENTS ACTION 4. -

With the number of channels OPERABLE'one less than required j

by the Minimum Channels OPERABLE requirement, verify compliance with the SHUTDOWN MARGIN requirements of Specification 3.1.1.1 or 3.1.1.2. as applicable, within.1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and at-least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter.

O Ta ACTION 5 -

With the' number of channels OPERABLE one less than required' by the Minimum Channels OPERABLE requirement, place'the reactor.

trip breakers of the inoperable channel in the tripped condition within I hour or be in HOT. STANDBY within 6 hour6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months s: however, one channel may be bypassed for up to I hour for surveillance testing per Specification 4.3.1.1.1.

I ACTION 6 a.

With one CEAC inoperable, operation may. continue for up to 7-days _provided that-at least once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months , each CEA is verified to be within-7 inches (indicated i

position) or all other CEAs in its group.

After 7'

'l days, operation may continue provided that. ACTION 6.b r

is met.

i b.

With both CEACs inoperable, operation may continue provided that:

1.

Within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months the margin required by Specification 3.2.4.b (COLSS in service) or Specification 3.2.4.d (COLSS out of service) is ld satisfied.

2.

Within 4 hour4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months s:

-i a)

All full length and part length CEA groups are withdrawn to and subsequently maintained at the " Full Out" position, except during

~

surveillance testing pursuant to the i

requirements of Specification 4.1.3.1.2 or

'l for control when CEA group 6 may be inserted no further than 127.5 inches withdrawn.

b)

The "RSPT/CEAC Inoperable" addressable constant in the CPCs is set to both CEACs inoperable.

c)

The Control Element Drive Mechanism Control D

System (CEDMCS) is placed in and j

subsequently maintained in the."0FF" mode except during CEA motion permitted by a) above, when the CEDMCS may be operated in N

either the " Manual Group" or " Manual Individual" mode.

i-ARKANSAS - UNIT 2 3/4 3 Sb Amendment No. 20,10,70,140,159

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TABlF 3.3 1 (Continued)

ACTION STATFMFNTS, 3.

'At least'once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . all full length and part length CEAs are verified fully withdrawn.

j except as permitted by~2. a) above. then verify at least.once per 4. hours that the inserted CEAs are aligned within~7 inches (indicated position) of all other CEAs in their group.

ljl With three or more auto restarts of one non-bypassed ACTION 7 calculator during a 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ' interval, demonstrate calculator OPERABILITY by performing a CHANNEL FUNCTIONAL TEST within-the next 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

']

With the number of OPERABLE channels one less than the ACTION 8 Minimum Channels OPERABLE requirement restore the inoperable i

channel to OPERABLE status within~48 hours or open the affected reactor trip breakers within the nt hour..The trip breakers associated with the inoperable channel may:be 1

closed for up to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months for surveillance testing per

~l Specification 4.3.1.1.

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i ARKANSAS - UNIT 2 3/4 3 Sc Amendment No. 49.49,159 i

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M TABLE 3.3-2

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REACTOR PROTECTIVE INSTRUMENTATION RESIJNSE TIMES z$

sn FUNCTIONAL UNIT RESPONSE TIME

'u 1.

Manual Reactor Trip Not Applicable.

2.

Linear Power level - High 1 0.40 seconds

3.

Logarithmic Power Level - High 1 0.40 seconds

4.

Pressurizer Pressure

.lligh

- 1 0.90 seconds 5.

Pressurizer Pressure - Low 1 0.90 seconds 6.

Containment Pressure - High 1 1.59 seconds m%

7.

Steam Generator Pressure - Low

's 0.90 seconds 8.

Steam Generator Level - Low

< 0.90 seconds.

9.

Local Power Density - liigh a.

Neutron Flux Power-from Excore Neutron Detectors

< 2.58 seconds *'

b.

CEA' Positions

~ 1.53 seconds **

1

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e TABIF 4_3 1 REACTOR PROTFCTION INSTRUMFNTATf0N SURVFitLANCF RF00fRFMENTS

CHANNEL, MODES'IN WHICH CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE FUNCTIONAt UNIT' CHFCK CAlfBRATf0N

___TFSTS RFOUIRFD'

.- l.

Manual Reactor Trip N.A.

N.A.

S/U(1)

N.A.

2.

Linear Power Level - High S

D(2,4).

M 1, 2 M(3,4),

O(4) 3.

Logarithmic Power Level - High 5

R(4)

M and S/U

1. 2. 3.-4.

5 L(1) and

4 Pressurizer Pressure - High S

R M

1. 2 5.

Pressurizer Pressure Low

-S R

H 1, 2

.3*.4*,5*

l 6.

Containment Pressure High 5

R M

1, 2 7.

Steam Generator Pressure Low -

S R

M.

1.-2

.3*.4*,5*

>l 8.

Steam Generator Level - Low S

R M

1, 2 9.

Local Power. Density High 5

D(2,4).

M. R(6) 1, 2 R(4,5) 10.

DNBR - Low S

S(7),

M. R(6),

1, 2 D(2.4),

M(8).

R(4,5) i 11.

Steam Generator level - High S

R H-1, 2 12.

Reacter Protection System Logic N.A.

N.A.

M-

1. 2

.3*,4*.E*

l!

13.

Reactor Trip Breakers N.A.

N.A.

M

1. 2

.3*.4*,5*

l 14.

Core Protection Calculators S. W(9) D(2.4).

M, R(6).-

1, 2 R(4.5) 15.

CEA Calculators S

R M. R(6).

1. 2 f

ARKANSAS - UNIT 2 3/4 3 7 Amendment No. 34, 39. J4,159

. 41

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TABtE 3_3 ENGINEFRF0 SAFETY FFATURE ACTUATION SYSTEM INSTRUMENTATION MINIMUM TOTAL NO.

CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNFLS JD TRIP QPERABLE MODES ACTION 1.

SAFETY INJECTION (SIAS) a.

Manual (Trip Butt i

2 sets of 2 1 set of 2 2 sets of 2 1.2.3.4 9

[.

b.

Containment Pressure -

High 4

2 3

1. 2. 3 10.11 l

c.

Pressurtzer Pressure -

Low 4

2 3

1. 2. 3(a) 10.11 l

d.

ESFAS Logic 1.

Matrix Logic 6

1 3

1. 2. 3 12 2.

Initiation logic 4

2 4

1. 2. 3, 4 9

e.

Automatic Actuation Logic 2

1 2

1.2.3.4 13 2.

CONTAINHENT SPRAY (CSAS) a.

Manual (Trip Buttons) 2 sets of 2 1 set of 2 2 sets of 2 1, 2. 3. 4-9 l.

b.

Containment Pressure --

High-- High 4

2(b) 3

1. 2. 3 10.11 l

c.

ESFAS Logic 1.

Matrix Logic.

6 1-3 1, 2. 3-12 2.

Initiation Logic-4.

2 4

1, 2. 3. ~ 4 9

d.

Automatic Actuation Logic 2

1 2

1.2.3.4 13 ARKANSAS - UNIT 2 3/4 3-11 Amendment No. 434,159

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TABtF 3.3-3 ENGINEERED SAFETY FEATURF ACTUATION SYSTEM INSTRUMENTATION MINIMUM TOTAL NO.

CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNFts TO TRIP QPERABLE MODES ACIIDH 3.

CONTAINMENT ISOLATION (CIAS) a.

Manual (Trip Buttons) 2 sets of 2 1 set of 2 2 sets of 2-

1. 2. 3, 4 9

l b.

Containment Pressure -

High' 4

2 3

1. 2. 3 -

10.11 l.

c.

ESFAS Logic 1.

Matrix Logic 6

1 3

1. 2. 3 12 2.

Initiation Logic 4

2 4

1.2,3.4 9

d.

Automatic Actuation Logic 2

1

1. 2. 3. 4 13 4.

MAIN STEAM AND FEEDWATER ISOLATION (MSIS) a.

Manual (Trip Buttons) 2 sets of 2 I set of 2 2 sets of 2

1. 2. 3, 4

.9 l

b.

Steam Generator 4/ steam 2/ steam 3/ steam

1. 2, 3

'10.11 l

Pressure - Low generator generator generator c.

ESFAS Logic 1.

Matrix Logic 6

1 3

1. 2, 3 -

12 2.

. initiation Logic 4'

2 4

1. 2. 3. 4 9

d.

Automatic Actuation Logic 2

1 2

1. 2. 3. 4 13 ARKANSAS - UNIT 2 3/4 3-lla Amendment.No. Eb6,159 j

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TABLE 3.3-3 (Continued 1 ENGIMFFRED SAFETY FEATURE ACTUATION SYSIEM INSTRUMFNTATION MINIMUM TOTAL NO.

CHANNELS CHANNELS APPLICABLE FUNCTIONAL _UNil DF CHANNELS TO TRIP __

QPERABLE MODES AC11DN 5.

CONTAINMENT COOLING (CCAS) a.

Manual (Trip Buttons) 2 sets of 2 I set of 2 2 sets of 2

1. 2. 3. 4 9-l b.

Containment Pressure -

High 4

2 3

1. 2, 3 10.11 l

c.

Pressurizer Pressure -

Low 4

2 3

1. 2. 3(a) 10.11' j'

d.

ESFAS Logic 1.

Matrix Logic 6

1 3

1, 2. 3 12 2.

Initiation Logic 4

2 4

1. 2, 3. 4 9

e.

Automatic Actuation Logic 2

1 2

1. 2. 3. 4 13 6.

RECIRCULATION (RAS) a.

Manual (TRIP Buttons)(c) 2 sets of 2 I set of 2 2 sets of 2

1. 2. 3. 4 9

l per train per train per train b.

_ Refueling Water Tank - Low 4

2 3

1. 2. 3 10.11

_l c.

ESFAS Logic 1.

Matrix Logic 6

1 3

1. 2, 3 12 2.

Initiation Logic 4

2 4

1. 2, 3. 4 9

d.

Automatic Actuation Logic-2 1

2

1. 2. 3. 4

~I3 ARKANSAS - UNIT 2 3/4 3-12 Amendment No. 444,159-

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. :3 -

- g4 TARl_E 3_3-3 1 Continued)

ENGINEERFD SAFETY FEATURF ACTUATION SYSTEM INSTRUMENTATIDM

~_

MINIMUM TOTAL NO.

CHANNELS CHANNELS APPLICABLE EllgCTIONAL UNIT OF.. CHANNELS TO TRIP OPERABLE M00ES ACTIOR 7.

LOSS OF POWER a.

4.16 kw Emergency Bus Undervoltage (Loss

.of Voltage) 2/8us 1/ Bus 2/ Bus

1. 2. 3 9

-l-b.

460 volt Emergency Bus Undervoltage-(Degraded Voltage) 1/ Sus 1/ Bus 1/ Bus

1. 2. 3 9

.l 8.

EMERGENCY FEEDWATER (EFAS) a.

Manual (Trip Buttons) 2 sets of 2

-1. set of 2 2 sets of 2

1. 2. 3. 4

' 9' j'

per S/G per S/G per 5/G b.

SG Level and Pressure r

(A/8) - Low.and AP (A/8) - High 4/SG 2/SG

.3/SG

1. 2. 3. 4 10.11 l

c.

'SG Level (A/8) --Low and No S/G Pressure -

Low Trip (A/8) 4/SG 2/SG 3/SG

1. 2. 3. 4 10.11 l.

d.

ESFAS Logic.

l..

Matrix Logic 6

1 3

1. 2. 3. 4'

~12-2.

Initiation Logic 4-2 4

-1.

2; 3. 4-9.

e.

Automatic-Actuation Logic 2

1 2

1. 2. 3. 4-

. 13 ARKANSAS.- UNIT 2 3/4'.3-13 Amendment:No.134J59 1

TABlF 3.3-3 (Continued)

TARIF NOTATION (a)

Trip function may be bypassed in this MODE when pressurizer pressure is below 400 psia; bypass shall be automatically removed when pressurizer pressure is 2 500 psia.

(b)

An SIAS signal is first necessary to enable CSAS logic.

(c)

Remote manual not provided for RAS.

These are local manuals at each ESF auxiliary relay cabinet.

ACTION STATEMFNTS ACTION 9 With the number of OPERABLE channels one less than the l

Total Number of Channels, restore the inoperable' channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

ACTION 10 With the number of channels OPERABLE one less than the Total Number of Channels. STARTUP and/or POWER OPERATION may continue provided the inoperable channel is placed in the bypassed or tripped condition within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

If the inoperable channel is bypassed for greater than 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months , the desirability of maintaining this channel in the bypassed condition shall be reviewed at the next regularly scheduled PSC meeting in accordance with Specification 6.5.1.7.n.

The channel shall be returned to OPERABLE status prior to startup following the next COLD SHUTDOWN.

With a channel process measurement circuit that affects multiple functional units inoperable or in test, bypass or trip all associated functional units as listed below.

Process Measurement circuit Functional Unit Byoassed

1. Containment Pressure - NR Containment Pressure High (RPS)

Containment Pressure - High (ESFAS)

Containment Pressure - High High (ESFAS)

2. Steam Generator 1 Pressure Steam Generator 1 Pressure Low Steam Generator 1 AP (EFAS 1)

Steam Generator 2 AP (EFAS 2)

3. Steam Generator 2 Pressure Steam Generator 2 Pressure Low Steam Generator 1 AP (EFAS 1)

Steam Generator 2 AP (EFAS 2)

4. Steam Generator 1 Level Steam Generator 1 Level Low Steam Generator 1 Level - High Steam Generator 1 AP (EFAS 1)

5. Steam Generator 2 Level Steam Generator 2 Level - Low Steam Generator 2 Level High steam Generator 2 AP (EFAS 2)

ARKANSAS - UNIT 2 3/4 3 Amendment No. 444.159

My 1 J..

- TABtF 3.3-3-(Continued)

'n.

. TARLF NOTATION ACTION 11-With'the number of channels OPERABLE one:less than the Minimum Channels OPERABLE requirement. STARTUP and/or POWER'0PERATION s

-may continue provided'the following conditions ~are satisfied:

a..

Verify that one of the inoperable channels has been' bypassed and place the other inoperable channel:1n the tripped'

~

condition within I hour, and I

b.

All functional units affected by the bypassed / tripped' channel shall also be placed in the bypassed / tripped conditionf u

as listed below:.

Process Measurement circuit Functional Unit Rvnassed/Trinned

1. Containment Pressure - NR Containment Pressure - High (RPS)'

r Containment. Pressure - High (ESFAS)

Containment Pressure High-High-(ESFAS) 3

2. Steam Generator 1 Pressure Steam Generator 1 Pressure - Low' Steam Generator 1 AP (EFAS 1)'

- 1 Steam. Generator ~2 AP (EFAS 2)

3. Steam Generator 2 Pressure Steam Generator 2 Pressure - Low l

Steam Generator 1 AP (EFAS 1)-

Steam Generator.2 AP (EFAS 2)

4. Steam Generator 1 Level Steam Generator 1 Level - Low-Steam Generator ILLevel -1High j

Steam Generator ~1 AP (EFAS 1)

5. Steam Generator 2 Level

--Steam Generator 2 Level - Low Steam Generator 2 Level - High Steam Generator 2 AP (EFAS-2)

STARTUP and/or' POWER OPERATION may continue'until the performanceL of the next required CHANNEL _ FUNCTIONAL TEST.

Subsequent,STARTUP and/or POWER OPERATION may continue if one channel is restored'to OPERABLE status and the provisions of ACTION 10 are satisfied.

ACTION 12 With the number of OPERABLE channels'one less than the Minimum Channels OPERABLE. restore the.inoperablefchannelito OPERABLE-status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within.the folicwing.30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

1 ACTION 13 With the number of OPERABLE channels one less than the Total q

Number of Channels, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in at least HOT STANDBY within-the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months s: however, one channel may be bypassed for up to I hour for surveillance testing provided the other channel is OPERABLE.

l 1

ARKANSAS - UNIT 2 3/4 3-15 Amendment No.159 '

I w

+

e v

n e

~

TAR 12 3.3 4 ENGillEERED SAPITY IIATURE ACTUATION STSTEN INSTRUNENTATION TRIP YAIRES i

~

ALLONABIA FUNCTIONAL UNIT TRIP SETPOINT VAIRES 1.

SAFETT INJECTION (SIAS) a.

Manual (Trip Buttons)

Not Applicable Not Applicable b.

Containment Pressure - High 5 18.3 psia 5 18.490 pela.

c.

Pressuriser Pressure -Low 21717.4 pois (1) 21686.3pela (1) 2.

CONTAINNENT SPRAT (CSAS) a.

Namuel (Trip Buttoes)

Not Applicable Not Applicable i

b.

Costalmeest Pressure -- High-High 5 23.3 psia 5 23.490 psia 1

3.

CONTAINNENT ISOLATION (CIAS) l a.

Manuel (Trip Buttons)

Not Applicable Not Applicable l

b.

Contaisseet Pressure - Nigh 5 18.3 psia 5 18.490 pela ARKANSAS - UNIT 2 3/4 3-16 Ameedeemt No. 24.131,138

' ~

p 3/4.3 INSTRUMENTATION BASES 3/4.3.1 and 3/4.3.2 PROTECTIVE AND ENGINEERED SAFETY FEATURES (ESF)

INSTRUMENTATION The OPERABILITY of the protective and ESF instrumentation systems and bypasses ensure that 1) the associated ESF action and/or reactor trip will be initiated when the parameter monitored by each channel or combination thereof reaches its setpoint, 2) the specified coincidence logic is maintained, 3) sufficient redundancy is maintained to permit a channel to be out of service for testing or maintenance, and 4) sufficient system functional capability is available for protective and ESF purposes from diverse parameters.

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

The integrated operation of each of these systems is consistent with the assumptions used in the accident analyses.

The surveillance requirements specified for these systems ensure that the overall system functional capability is maintained comparable to the original design standards.

The periodic surveillance tests performed at the minimum frequencies are sufficient to demonstrate this capability.

The measurement of response time at the specified frequencies provides assurance that the protective and ESF action function associated with each channel is completed within the time limit assumed in the accident analyses.

No credit was taken in the analyses for those channels with response times indicated as not applicable.

Response time may be demonstrated by any series of sequential, overlapping or total channel cest measurements provided that such tests demonstrate the total channel response time as defined.

Sensor response time verification may be demonstrated by either 1) in place, unsite or off site test measurernents or 2) utilizing replacement sensors witn ceN T.r(

response times.

RTD response time is defined as the time interval required for the RTD output to achieve 63.2% of its total change when subjected to a step change in RTD temperature.

The RTD response time for the Core Protection Calculator System (CPCS) is expressed as an effective time constant.

For hot leg temperatures, the effective time constant for a given CPC channel is defined as the mean time constant for averaged pairs of hot leg RTD inputs to the channel.

This is done because the CPCS utilizes the mean hot leg temperature IJ its calculations.

The maximam hot leg effective time constant allowable for use in the CPCS is 13.0 seconds.

For cold leg temperatures, the effective time constant to be used in Figure 3.3-1 is the maximum time constant of the two cold leg RTD inputs for a given channel.

The CPCS utilizes the more conservative cold leg temperature in the various DNBR and LPD calculations.

The maximum cold leg effective time ccnstant allowable for use in the CPCS is 13.0 seconds.

ARKANSAS - UNIT 2 B 3/4 3-1 Amendment No. 77. 79

~

_.__- - _ - ~

m j

-3/4.3 INSTRUMENTATION BASES l

Plant Protective SystemL(PPS) logic-is designed for operation as a 2-out of-3 logic, although.normally it is operated in a 2 out of-4 mode.

The RPS. Logic consists of everything' downstream of the bistable relays and upstream of'the. Reactor Trip Circuit Breakers.

The RPS Logic is divided into two parts. Matrix Logic. and Initiation Logic-Failures of. individual bistables and their relays are considered '

measurement channel failures.

i The ESFAS Logic consists of everything downstream of the bistable y

relays and upstream of the subgroup relays.- The ESFAS Logic is divided into three parts Matrix. Logic. Initiation Logic, 'and Actuation Logic.. Failures = of individual bistables and their relays i

are considered measurement channel failures.

1 Matrix Logic refers to the matrix power supplies, trip channel bypass 5

contacts and interconnecting matrix wiring between bistable relay cards, up to, but not including the matrix relays.

Matrix contacts on the bistable relay cards are excluded from the Matrix Logic-definition since they are addressed as part of the measurement

- channel.

Initiation Logic consists of the trip path power source, matrix relays and their associated contacts', all-interconnecting wiring, and i

the initiation relays (including contacts).-

ESFAS Actuation. Logic consists of.all circuitry housed within the Auxiliary Relay Cabinets (ARCS) used to house the ESF Function:

i excluding the. subgroup-relays, and, interconnecting wiring.to.the j

initiation relay. contacts mounted in the PPS cabinet.

I For the purposes of this LCO, de-energization of up.to three matrix power supplies due.to a single failure, such as loss of a vital.

Instrument bus. is to be treated as a single matrix channel failure,

_ providing the affected matrix relays de energize'as designed to produce a half-trip.

Although each of the six matrices _within an ESFAS Function (e.g..-SIAS MSIS, CSAS, etc.) uses separate power

-supplies, the matrices for the different ESFAS Functions share power R

supplies.

Thus, failure of a matrix power supply may: force' entry into the Condition specified for each of the associated ESFAS Functional Units.

ARKANSAS - UNIT 2 B 3/4 3 la Amendment No.159

/,l ADMfMIETTATIVE CONTR01.M l

t 6.5.2 RATETY REVIEW COMMITTEE (SRC)

$TNCTION 6.5.2.1 The Safety Review Committee shall function to provide independent review and audit of designated activities in the areas of:

a.

nuclear power plant operations g

b.

nuclear engineering,

)

c.

chemistry and radiochemistry d.

metallurgy e.

instrumentation and control f.

radiological safety q

g.

mechanical and electrical engineering h.

quality assurance practices COMPOSITION j

l 6.5.2.2 The Safety Review Committee shall be composed of a Chairmar..nd eight to twelve members which collectively have the experience

'1 and competence required by ANSI /ANS-3.1-1981 to review problems in the areas specified in Section 6.5.2.1, a-h.

The Vice President, Operations ANO shall designate, in writing, the Chairman and all SRC members.

The Chairman shall designate, in writing, the alternate Chairman in the absence of the SRC Chairman.

ARKANSAS - UNIT 2 6-8 Amendment No. J,J7,2),J2,1) 77,78,114

t ADMINISTRATIVE CONTROLS f.

Review of all REPORTABLE EVENTS.

g.

Review of facility operations to detect potential nuclear safety

hazards, h.

Performance of special reviews, investigations or analyses, and reports thereon as requested by the Plant Manager, ANO 2, General Manager, Plant Operations or the-Safety Review Committee.

1.

Review of the Plant Security Plan and submittal of recommended changes to the General Manager, Plant Operations and the Safety Review Committee.

j.

Review of the Emergency Plan and submittal of recommended changes to the General Manager, Plant Operations and Safety Review Committee.

k.

Review of changes to the Offsite Dose Calculation Manual and Process Control Program.

1.

Review of changes to the Fire Protection Program and submittal of recommended changes to the General Manager, Plant Operations and Safety Review Committee.

m.

Review of proposed procedures and changes to procedures which involve an unreviewed safety question as defined in 10CFR50.59.

Review and documentation of judgment concerning extended operation n.

(longer than 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months ) with a PPS trip channel in bypass.

Review shall determine whether to leave the trip channel in bypass, place the channel in trip, and/or repair the defective channel.

AUTHORITY 6.5.1.8 The Plant Safety Committee shall:

Recommend in writing their approval or disapproval of. items a.

considered under 6.5.1.6(a) through (d) above, b.

Render determinations in writing with regard to whether or not each item considered under 6.5.1.6(a) through (e) above constitutes an unreviewed safety question.

c.

Provide written notification within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months to the Vice President, Operations ANO and the Safety Review Committee of disagreement between the PSC and the Plant Manager, ANO 2 or the General Manager, Plant Operations; however, the General Manager, Plant Operations shall have responsibility for resolution of such disagreements pursuant to 6.1.1 above.

RECORDS 6.5.1.9 The Plant Safety Committee shall maintain written minutes of each i

PSC meeting that, at a minimum, document the results of all PSC activities performed under the responsibility and authority provisions of these technical specifications.

Copies shall be provided to the Plant Manager,

}

ANO-2. General Manager, Plant Operations and Chairman of the Safety Review Committee.

ARKANSAS - UNIT 2

,67 Amendment No. 6.44,36,63.60,

+csgGl.98.44.M9.M3 M,

ML20082F830

Text

Attachment:

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