ML20044D100

Proposed Tech Specs Reflecting Correction of Typos to Improve Legibility

ML20044D100
Person / Time
Site:	Arkansas Nuclear
Issue date:	05/07/1993
From:	ENTERGY OPERATIONS, INC.
To:
Shared Package
ML20044D097	List: 2CAN059302, Application for Amend to License NPF-6,correcting Typos ML20044D100
References
NUDOCS 9305170231
Download: ML20044D100 (20)

Text

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PROPOSED TECHNICAL SPECIFICATION CHANGES k

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l 9305170231 930507 t

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-pEFINITIONS i

i GASEOUS RADWASTE TREATMENT SYSTEM

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1.31 A GASEOUS RADWASTE TREATMENT SYSTEM is any system designed and installed to reduce radioactive gaseous effluents from the plant by collecting offgases from radioactive systems and providing for decay or holdup for the purpose of reducing the total radioactivity prior to release to the environment.

VENTILATION EXHAUST TREATMENT SYSTEM l

1.32 A VENTILATION EXHAUST TREATMENT SYSTEM is any system designed and installed to reduce gaseous radiciodine or radioactive material in particulate j

form in effluents by passing ventilation or vent exhaust gases through charcoal adsorbers and/or HEPA filters for the purpose of removing lodines or particulates from the gaseous exhaust stream prior to the release to the environment. Such a system is not considered to have any effect on noble gas l

effluents. Atmospheric cicanup systems that are Engineered Safety Feature (EST)

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actuated are not considered to be VENTILATION EXHAUST TREATMENT SYSTEMS.

MEMBER (S) OF THE PUBLIC f

1.33 MEMBER (S) 0F THE PUBLIC shall include all persons who are not occupationally associated with the plant.

T;.is category does not include _

employees of the utility, its contractors or vendors. Also excluded from this i

category are persons who enter the site to service equipment or to make deliveries. This category does include persons who use portions of the site for recreational, occupational or other purposes not associated with the plent.

PURGE-PURGING 1.34 PURGE or PURGING is the controlled process of discharging air or gas from a confinement to reduce airborne radioactive concentrations in such a manner that replacement air or gas is required to purify the confinement.

I EXCLUSION AREA 1

1.35 The EXCLUSION AREA is that area surrounding ANO within a minimum radius of

.65 miles of the reactor buildings and controlled to the extent necessary by the j

licensee for purposes of protection of individuals from exposure to radiation j

and radioactive materials.

UNRESTRICTED AREA f

1.36 An UNRESTRICTED AREA shall be any area at or beyond the exclusion area l

boundary.

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ARKANSAS - UNIT 2 1-7 Amendment No. 60

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t 3/4.1. REACTIVITY CONTROL SYSTEMS 3/4.1.1 BORATION CONTROL i

SHUTDOWN MARGIN T 5 200*F avg l

i L_IMITING CONDITION FOR OPERATION i

3.1.1.1 The SHUTDOWN MARGIN shall be 25.5% Ak/k.

i APPLICABILITY: MODES 1, 2*,

3 and 4.

t ACTION:

i With the SHUTDOWN MARGIN <5.5% Ak/k, immediately initiate and continue boration at 240 gpm of 2500 ppm boric acid solution or equivalent until the required SHUTDOWN MARGIN is restored.

SURVETLLANCE REOUIREMENTS

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4.1.1.1.1 ine SHUTDOWN MARGIN shall be determined to be 25.5% Ak/k.

i a.

Within one hour after detection of an inoperable CEA(s).and at

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least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> thereafter while the CEA(s) is inoperable.

If the inoperable CEA is immovable or untrippable, the above required SHUTDOWN MARGIN shall be increased by an amount at least equal to the withdrawn worth of the immovable or untrippable CEA(s).

b.

When in MODES 1 or 2, at Icast once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> by verifying that CEA group withdrawal is within the Transient Insertion Limits of Specification 3.1.3.6.

c.

When in MODE 2, within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> prior to achieving reactor criticality by verifying that the predicted critical CEA

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position is within the limits of Specification 3.1.3.6.

j d.

Prior to initial operation above 5% RATED THERMAL POWER after each fuel loading, by consideration of the factors of (c) below, with the CEA groups at the Transient Insertion Limits of Specification 3.1.3.6.

j See Special Test Exception 3.10.1.

f With K,ff 2 1.0.

With K,ff ( 1.0.

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ARKANSAS - UNIT 2 3/4-1-1 Amendment No f4, 82 I

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i REACTIVITY CONTROL SYSTEMS FLOW PATHS - OPERATING LIMITING CONDITION FOR OPERATION 3.1.2.2 The following boron injection flow paths shall be OPERABLE, depending on the volume available in the boric acid makeup i

tanks.

If the contents of ONE boric acid makeup tank meet the volume a.

requirements of Figure 3.1-1, two of the following three flow paths to the Reactor Coolant System shall be OPERABLE:

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1.

One flow path from the appropriate boric acid makeup tank l

via a boric acid makeup pump and a charging pump.

f 2.

One flow path from the appropriate boric acid makeup tank l

via a gravity feed connection and a charging pump.

i 3.

One flow path from the refueling water tank via a charging pump.

DE b.

If the contents of Both boric acid tanks are needed to meet the volume requirements of Figure 3.1-1, four of the following five flow paths to the Reactor Coolant System shall be OPERABLE:

1.

One flow path from boric acid makeup tank A via a boric acid makeup pump and a charging pump.

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One flow path from boric acid makeup tank B via a boric j

acid makeup pump and a charging pump.

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One flow path from boric acid makeup tank A via a gravity I

feed connection and a charging pump.

e 4.

One flow path from boric acid makeup tank B via a gravity feed connection and a charging pump.

5.

One flow path from the refueling water tank via a chsrging.

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pump.

j APPLICABILITY: MODES 1, 2, 3 and 4

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ACTION:

With any of the boron injection flow paths to the Reactor Coolant System j

required in (a) or (b) above inoperable,- restore the inoperable ' flow path to the Reactor Coolant System to OPERABLE status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or be in i

I at least HOT STANDBY and borated to a SHUTDOWN MARGIN equivalent to at least <5% Ak/k at 200 F within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />; restore the flow paths to.

OPERABLE status within the next 7 days or be in COLD SHUTDOWN within the next 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.

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ARKANSAS - UNIT 2 3/4 1-8 Amendment No. JA, 82

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, REACTIVITY CONTROL SYSTEMS l

SURVETIJ.ANCE REOUIREMENTS (Continued) i a.

At least once per 7 days by:

1.

Verifying the boron concentration in each water source, 2.

Verifying the contained borated water volume in each water source, and 3.

Verifying the boric acid makeup tank (s) solution

~1 temperature is greater than 55'F.

b.

At least once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> by verifying the RWT temperature.

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ARKANSAS'- UNIT 2 3/4 1-16 Amendment No. 82

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I REACTIVITT CONTROL SYSTEMS

.i 3/4.1.3 MOVABLE CONTROL ASSEMBLIES

-j CEA POSITION t

_I1MITING CONDITION FOR OPERATION f

3.1.3.1 All full length (shutdown and regulating) CEAs, and all part length CEAs which are inserted in the core, shall be OPERABLE with each CEA of a given group positioned within 7 inches (indicated position) of

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all other CEAs in its group.

APPLICABILITY: MODES 1* and 2*.

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ACTION:

a.

With one or more full length CEAs inoperable due to being l

immovable as a result of excessive friction or mechanical interference or known to be untrippable, determine that the SHUTDOWN MARGIN requirement of Specification 3.1.1.1 is satisfied within I hour and be in at least HOT STANDBY within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

i b.

With one full length CEA trippable but inoperable due to causes other than addressed by ACTION (a), above, and inserted beyond the Long Term Steady State Insertion Limits but within its above specified alignment requirements, operation in MODES 1 and 2 may I

continue pursuant to the requirements of Specification 3.1.3.6.

i c.

With one full length CEA trippable but inoperable due to causes other than addressed by ACTION (a), above, but within its above specified alignment requirements and either fully withdrawn or within the Long Term Steady State Insertion Limits if in full length CEA group 6, operation in MODES 1 and 2 may continue.

d.

With more than one full length or part length CEA trippable but

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inoperable due to causes other than addressed by ACTION a, above, restore the inoperable CEA(s) to OPERABLE status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />, or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

With one or more full length or part length CEAs trippable but l

c.

misaligned from any other CEAs in its group by more than 7 l

inches but less than or equal to 19 inches, operation.in MODES 1 li and 2 may continue, provided that core power is reduced in accordance with Figure 3.1-1A and within 1 bour the misaligned CEA(s) is either:

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Restored to OPERABLE status within its above specified i

alignment requirements, or

• See Special Test Exceptions 3.10.2 and 3.10.4.

ARKANSAS - UNIT 2 3/4 1-17 Amendment No. 75, 125

e TABLE 3.3-1 (Coatinued)

ACTION STATEMENTS b.

With both CEACs inoperable, operation may continue provided that:

1.

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

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2.

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

a)

All full length and part length CEA groups are withdrawn to and subsequently maintained at the " Full Dut" position, except during surveillance testing pursuant to the requirements of Specification 4.1.3.1.2 or 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 System (CEDMCS) is placed in and subsequently maintained in the "0FF" mode except during CEA motion permitted by a) above, when the CEDMCS may be operated in either the " Manual Group" or " Manual Individual" mode.

3.

At least once per 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />, all full length and part length CEAs are verified fully withdrawn, except as permitted by 2.a) above, then verify at least once per 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> that the inserted CEAs are aligned within 7 inches (indicated position) of all other CEAs in their group.

ACTION 6 -

With three or more auto restarts of one non-bypassed calculator during a 12-hour interval, demonstrate calculator OPERABILITY by performing a CHANNEL FUNCTIONAL TEST within the next 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

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ARKANSAS - UNIT 2 3/4 3-Sa Amendment No. 26,47,79

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TABLE 3.3-4 (Continued)

ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION TRIP VALUES ALLOWABLE FUNCTIONAL UNIT TRIP VALUE VALUES 4.

MAIN STEAM AND FEEDWATER ISOLATION (MSIS) a.

Manual (Trip Buttons)

Not Applicable Not Applicable b.

Steam Generator Pressure - Low 2 751 psia (2) 2 729.613 psia (2) 5.

CONTAINMENT COOLING (CCAS) a.

Manual (Trip Buttons)

Not Applicable Not applicable b.

Containment Pressure - High 5 18.3 psia 5 18.490 psia c.

Pressurizer Pressure - Low 2 1717.4 psia (1) 21686.3 psia (1) 6.

RECIRCULATION (RAS) a.

Manual (Trip Buttons)

Not Applicable Not Applicable b.

Refueling Water Tank - Low 54,400 i 2,370 gallons between 51,050 and 58,600 (equivalent to 6.0 1 0.5%

gallons (equivalent to indicated level) between 5.111% and 6.889%

indicated level) 7.

LOSS OF POWER a.

4.16 kv Emergency Bus Undervoltage (Loss of Voltage) 3120 volts (4) 3120 volts (4) b.

460 volt Emergency Bus Undervoltage 423 1 2.0 volts 423 1 4.0 volts (Degraded Voltage) with an 8.0 1 0.5 with an 8.0 1 0.8 second time delay second time delay ARKANSAS - UNIT 2 3/4 3-17 Amendment No. 24, J)1, 138

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

TSI APPLICABLE 368-02-00

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INSTRUMENTATION RADIOACTIVE GASEOUS EFFLUENT MONITORING INSTRUMENTATION LIMITING CONDITION FOR OPE _ RATION 3.3.3.9 The radioactive gaseous effinent monitoring instrumentation channels shown in Table 3.3-12 shall be OPERABLE with their alarm / trip setpoints set to ensure that the limits of r

Specification 3.11.2.1 are not exceeded.

I APPLICABILITY:

During releases via this pathway.

ACTION:

a.

With the following gaseous effluent monitoring in-strumentation channels alarm / trip setpoint less con-t servative than required by the above specification, immediately suspend the release of radioactive t

gaseous effluents monitored by the affected channel.

1. Waste Gas Holdup System Noble Gas Activity l

Monitor (during periods of gaseous releases.)

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2. Containment Purge and Ventilation System Noble Gas Activity Monitor (during periods of containment building PURGE.)

b.

With less than the minimum number of monitoring instrumentation channels OPERABLE, take the action shown in Table 3.3-12.

c.

Return the instruments to OPERABLE status within 30 days or, in lieu of any other report, explain in the next Semiannual Radioactive Effluent Release Report why the inoperability was not corrected.

f d.

The provisions of Specifications 3.0.3 and 4.0.4 are f

not applicable.

SURVEILLANCE REOUIREMENTS 4.3.3.9 Each radioactive gaseous effluent monitoring instrumenta-tion channel shall be demonstrated OPERABLE by performance of the CHANNEL CHECK, SOURCE CHECK, CHANNEL CALIBRATION, and CHANNEL FUNCTIONAL TEST at the frequencies shown in Table 4.3-12.

k ARKANSAS - UNIT 2 3/4 3-45 Amendment No. (9,PJ, 134

a CONTAINMENT SYSTEMS SURVETLLANCE REOUIREMENTS i

4.6.2.3 Each containment cooling group shall be demonstrated OPERABLE:

a.

At least once per 14 days by:

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1.

Verifying that service water flow rate to each group of cooling units is 2 1250 gpm and that each unit in each group has an operable fan; or that one unit in each group has a i

service water flow rate of 2 1250 gpm and an operable fan.

t 2.

Addition of a biocide to the service water during the surveillance in 4.6.2.3.a.1 above, whenever service water temperature is between 60'F and 80'F.

b.

At least once per 31 days by:

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Starting (unless already operating) each operational cooling unit from the control room.

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2.

Verifying that each operational cooling unit operates for at

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1 east 15 minutes.

At least once per 18 months by verifying that each cooling unit i

c.

starts automatically on a CCAS test signal.

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f ARKANSAS - UNIT 2 3/4 6-15 Amendment No. JA,J6,27,107

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f CONTAINMENT SYSTEMS SURVETLLANCE REOUIREMENTS (Continued)

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4.6.3.1.2 _Each isolation valve specified in Table 3.6-1 shall be demonstrated OPERABLE during the. COLD SHUTDOWN or REFUELING MODE at least j

once per 18 months by verifying that on a containment isolation test

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signal, each isolation valve actuates to its isolation position.

j 4.6.3.1.3 The isolation time of each power operated or automatic valve of i

Table 3.6-1 shall be determined to be within its limit when' tested

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pursuant to Specification 4.0.5.

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4.6.3.1.4 Prior to exceeding conditions which require establishment of j

reactor building integrity per Specification 3.6.1.1, the leak rate of the containment purge supply and exhaust isolation valves listed in Table l

3.6-1 Part B shall be verified to be within acceptable limits per Specification 4.6.1.2, unless the test has been successfully completed j

within the last three months.

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I ARKANSAS - UNIT.2 3/4 6-17 Amendment No. 46

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l PLANT SYSTEMS F

3/4.7.12 SPENT FUEL POOL STRUCTURAL INTEGRITY i

_IMITING CONDITION FOR OPERATION f

L 3.7.12 The structural integrity of the spent fuel pool shall be maintained

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in accordance with Specification 4.7.12.

1 APPLICABILITY: Whenever irradiated fuel assemblies are in the spent fuel pool.

ACTION:

c a.

With the structural integrity of the spent fuel pool not conforming to the above requirements, in lieu of any other report, prepare and submit a Special Report to the Commission pursuant to Specification 6.9.2 within 30 days of a determination of such non-conformity.

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b.

The provisions of Specification 3.0.3 are not applicable.

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SURVE_I_I; LANCE REOUIREMENTS

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i 4.7.12.1 Insoection Frecuencies - The structural integrity of the spent i

fuel pool shall be determined per the acceptance criteria of Specification 4.7.12.2 at the following frequencies:

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At least once per 92 days after the pool is filled with water.

If no abnormal degradation or other indications of structural distress are detected during-five consecutive inspections, the inspection interval may be extended to at least once per 5 years.

4 b.

Within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> following any seismic event which actuates or i

should have actuated the seismic monitoring instrumentation of Specification 3.3.3.3.

.l 4.7.12.2 Accentance Criteria - The structural integrity of the spent fuel pool shall be determined by a visual inspection of at least the interior and j

exterior surfaces of the pool, the struts in the tilt pit, the surfaces of the separation walls, and the structural slabs adjoining the pool walls.

This visual inspection shall verify no changes in the concrete crack -

I patterns, no abnormal degradation or other signs of structural distress

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(i.e, cracks, bulges, out of plumbness, leak. age, discolorations, efflorescence, etc.).

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- ARKANSAS - UNIT 2 3/4 7-38 Amendment No. 7J,117 l

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ELECTRICAL POWER SYSTEMS SHUTDOWN LIMITING CONDITION FOR OPERATION 3.8.1.2 As a minimum, the following A.C. electrical power sources shall i

I be OPERABLE-i 1

a.

One circuit between the offsite transmission network and the

' i onsite Class IE distribution system, and j

L b.

One diesel generator with:

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1.

A day fuel tank containing a minimue volume of 280 gallons of fuel (equivalent to 50% of total tank volume),

2.

A fuel storage system containing a minimum volume of 22,500 l

gallons of fuel (equivalent to 100% of total tank volume),

and I

3.

A fuel transfer pump.

l APPLICABILITY: MODES 5 and 6.

l ACTION:

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With less than the above minimum required A.C. electrical power sources l

OPERABLE, suspend all operations involving CORE ALTERATIONS or positive j

reactivity changes.

4 SURVEILLANCE REOUIREMENT i

4.8.1.2 The above required A.C. electrical power sources shall be

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demonstrated OPERABLE by the performance of each of the Surveillance f

Requirements of 4.8.1.1.1 and 4.8.1.1.2 except for Requirement:

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4.8.1.1.2a.5.

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ARKANSAS - UNIT 2 3/4 8-5 I

t SPECIAL TEST EXCEPTIONS l

l REACTOR COOLANT LOOPS i

l LIMITING CONDITION FOR OPERATION I

3.10.3 The limitations of Specification 3.4.1.1 and noted requirements of l

Table 3.3-1 may be suspended during the performance of startup and PHYSICS TESTS, provided:

l a.

The THERMAL POWER does not exceed 5% of RATED THERMAL POWER, and b.

The reactor trip setpoints of the OPERABLE power level channels l

are set at 5 20% of RATED THERMAL POWER.

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APPLICABILITY: During startup and PHYSICS TESTS.

i ACTION:

i With the THERMAL POWER > 5% of RATED THERMAL POWER, immediately trip the f

reactor.

i SURVEILLANCE REOUIREMENTS 4.10.3.1 The THERMAL POWER shall be determined to be 5 5% of RATED j

THERMAL POWER at least once per hour during startup and PHYSICS TESTS.

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l 4.10.3.2 Each wide range logarithmic and power level neutron flux monitoring channel shall be subjected to a CHANNEL FUNCTIONAL TEST within

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12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> prior to initiating startup or PHYSICS TESTS.

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-ARKANSAS - UNIT 2 3/4 10-3

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j 3/4.11 RADIOACTIVE EFFLUENTS l

3/4.11.1 LIOUID EFFLUENTS l

LIMITING CONDITION FOR OPERATION 3.11.1.1 The concentration of radioactive material released from the site l

In liquid effluents to the discharge canal shall be limited to the concentrations specified in 10 CFR Part 20, Appendix B, Table II, Column 2 i

for radionuclides other than dissolved or entrained noble gases. For dissolved or entrained noble gases, the concentration released shall be i

limited to 2 x 10-' pCi/ml.

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APPLICABILITY: At all times.

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ACTION:

a.

With the concentration of radioactive material released exceeding

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the above limits,-immediately initiate actions to restore concentrations to within the above limits. Provide notification to the Commission within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> and in lieu of any other report, submit a Special Report pursuant to Specification 6.9.2.h

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b.

The provisions of Specifications 3.0.3 are not applicable.

SURVEILLANCE REOUIREMENTS 4.11.1.1.1 Radioactive liquid wastes shall be sampled and analyzed i

according to the sampling and analyses program of Table 4.11-1.

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4.11.1.1.2 The results of the radioactivity analyses shall be used in a

accordance with the methods ir. the ODCM to assure that the concentrations :

I at the point of release are maintained within the limits of Specification i

3.11.1.1.

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ARKANSAS - UNIT 2 3/4 11-1 Amendment No. f$, 134 I

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h TABLE 4.11.2 (Continued)

TABLE NOTATION i

a.

The Lower Limit of Detection (LLD) is defined in Table Notation a. of Table 4.11-1 of Specification 3.11.1.1.

t b.

The principal gamma emitters for which the LLD specification will apply are exclusively the following radionuclides:

Kr-87, Kr-88, Xe-133, s

Xe-133m, Xe-135, and Xe-138 for gaseous emissions and Mn-54, Fe-59, Co-58, Co-60, Zn-65, No-99, Cs-134, Cs-137, Ce-141 and Ce-144 for particulate emissions. This list does not mean that only these nuclides are to be detected and reported. Other peaks which are measurable and identifiable, together with the above nuclides, shall also be identified and reported. Nuclides which are below the LLD for the analyses should not be reported as being present at the LLD level for that nuclide. When unusual circumstances result in LLD's higher than required, the reasons shall be documented in the Semiannual Radioactive Effluent Release Report.

Tritium grab samples shall be taken from the Reactor Building c.

ventilation exhaust at least once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> when the refueling canal is flooded.

d.

Tritium grab samples shall be taken at least once per 7 days from the ventilation exhaust from the spent fuel area, whenever spent fuel is in the spent fuel pool.

The ratio of the sampic flow rate to the sampled stream flow rate shall e.

be known for the time period covered by each dose or dose rate calculation made in accordance with Specifications 3.11.2.1, 3.11.2.2, and 3.11.2.3.

f.

Samples shall be changed at least once per 7 days and analyses shall be completed within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> after changing (or after removal from the sampler).

g.

For certain radionuclides with low gamma yield or low energies, or for certain radionuclide mixtures, it may not be possible to measure radionuclides in concentrations near the LLD. Under these circumstances, the LLD may be increased inversely proportional to the magnitude of the gamma yield (i.e., 1 x E-4/I, where I is the photon abundance expressed as a decimal fraction), but in no case shall the LLD, as calculated in this manner for a specific radionuclide, be greater than 10% of the MPC value specified in 10 CFR 20, Appendix B, Table II, Column I.

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ARKANSAS - UNIT 2 3/4 11-9 Amendment No. (p,94 i

i BASES (Continued) 4.0.3 establishes the failure to perform a Surveillance Requirement within j

the allowed surveillance interval, defined by the provisions of Specification 4.0.2, as a condition that constitutes a failure to meet the

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OPERABILITY requirements for a Limiting Condition for Operation. Under the provisions of this specification, systems and components are assumed to be j

OPERABLE when Surveillance Requirements have been satisfactorily performed within the specified time interval. However, nothing in this provision is

-l to be construed as implying that systems or components are OPERABLE when j

they are found or known to be inoperable although still meeting the Surveillance Requirements. This specification also clarifies that the I

ACTION requirements are applicable when Surveillance Requirements have not been completed within the allowed surveillance interval and that the time limits of the ACTION requirements apply from the point in time it is identified that a surveillance has not been performed and not at the time i

that the allowed surveillance interval was exceeded. Completion of the Surveillance Requirements within the allowable outage time limits of the r

i ACTION requirements restores compliance with the requirements of Specification 4.0.3.

However, this does not negate the fact that the failure to have performed the surveillance within the allowed surveillance i

interval, defined by the provisions of Specification 4.0.2 was a violation of the OPERABILITY requirements of a Limiting Condition for Operation that is subject to enforcement action. Further, the failure to perform a surveillance within the provisions of Specification 4.0.2 is a violation of a Technical Specification requirement and is, therefore, a reportable event under the requirements of 10CFR 50.73(a)(2)(1)(B) because it is a condition prohibited by the plant's Technical Specifications.

j t

If the allowable outage time limits of the ACTION requirements are less than 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> or a shutdown is required to comply with ACTION requirements, e.g., Specification 3.0.3, a 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> allowance is provided to permit a 4

delay in implementing the ACTION requirements. This provides an adequate time limit to complete Surveillance Requirements that have not been l

performed. The purpose of this allowance is to permit the completion of a i

surveillance before a shutdown is required to comply with ACTION l

j requirements or before other remedial measures would be. required that may l

preclude completion of a surveillance. The basis for this allowance j

includes consideration for plant conditions, adequate planning, l

availability of personnel, the time required to perform the surveillance, and the safety significance of the delay in completing the required surveillance. This provision also provides a time limit for the completion of Surveillance Requirements that become applicable as a consequence of mode changes imposed by ACTION requirements and for ccapleting Surveillance Requirements that are applicable when an exception to the requirements of Specification 4.0.4 is allowed.

If a surveillance is not completed within the 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> allowance, the time limits of the ACTION requirements are applicable at that time. When a' surveillance is performed within the 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> allowance and the Surveillance Requirements are noc met, the time j

limits of the ACTION requirements are applicable at the time that the surveillance is terminated.

If the ACTION requirements are greater than 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, sufficient time exists to complete the surveillance.

1 ARKANSAS - UNIT 2 B 3/4 0-3 Amendment No. 134

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'l

}

- l i

BASES

+

1.

Tbc ".astrument indicates measured levels above the alarm / trip

{

setpoint.

2.

Power to the detector is lost.

3.

The instrument indicates a downscale failure.

i For the containment purge and the waste gas holdup system noble gas

' t activity moni* ors, the CHANNEL FUNCTIONAL TEST also demonstrates the l

automatic isolation of the release pathway occurs if the instrument j

l3*

indicates above the trip setpoint.

1 i

T1.e initial CHANNEL CALIBRATION is performed using one or more of the reference standards certified by the National Bureau of Standards or using j

standards that have been obtained from suppliers that participate in measurement assurance activities with NES.

These standards permit I

1 1

calibrating the system over its intended range of energy and measurment l

range. For subsequent CHANNEL CALIBRATION, sources that have been related j

to the initial calibration are used.

')

3.4.3.3.10 RADIDACTIVE LIDUID EFFLUENT INSTRUMENTATION t

I The radioactive liquid effluent instrumentation is provided to monitor and control, as applicabis, the relnases of radioactive materials in liquid effluents during actual or potential, releases of liquid-effluents.

The alarm / trip setpoints for these instruments shall be l

calculated in accordance with the procedures in the ODCH to ensure that the alarm / trip will occur prior to exceeding the If mits of 10 Cik im-t 20.

l

?

For the radioactive liquid effluent instrumentation surveillance.

l

l requirements, the channel test demonstrates that automatic laolation of 1

this pathway and control room alarm annunclution occur if the instrument

'i indicates measured levels above the trip setpoint. The channel test j

demonstrates that alarm annunciation occurs if any of the following conditions exist:

1

-l I

1.

Power to the detector is lost.

l l

2.

The instrument indicates a downscale failure.

3.

Instrument controls are not set in the operate mode.

The initial CHANNEL CALIBRATION is performed using one or more of the reference standards certified by the National Bureau of Standards or using standards that have been obtained from suppliers that participate in l

l l

)

I i

ARKANSAS - UNIT 2 B 3/4 3-4 Amendment No. 60 j

i i

=

h

~

1/4.4 ' 9EAGTOR QROLAYLT SYSTEM i

BASES 3/4.4.1 REACTOR COOLANT LOOPS AND COOLANT CIRCULATION i

i

?

The plant is designed to operate with bou, reactor coolant loops and associated reactor coolant pumps in operation, and maintain DNBR above the limits specified by Specification 3.2.4 during all normal operations and anticipated transients.

In MODE 3, a single reactor coolant loop provides sufficient heat removal capability for removing decay heat; however, single failure considerations require that two loops be OPERABLE.

I In MODES 4 and 5, a single reactor coolant loop or shutdown cooling

[

loop provides sufficient heat removal capability for removing decay heat; but single failure considerations require that at least two loops be OPERABLE. Thus, if the reactor coolant loops are not OPERABLE, this specification requires two shutdown cooling loops to be OPERABLE.

l 1

The operation of one Reactor Coolant Pump or one shutdown cooling i

pump provides adequate flow to ensure mixing, prevent stratification and produce gradual reactivity changes during boron concentration reductions in the Reactor Coolant System. The reactivity change rate associated with

{

boron reductions will, therefore, be within the capability of operator recognition and control.

3/4.4.2 and 3/4.4.3 SAFETY VALVES

{

1 The pressurizer code safety valves operate to prevent the RCS from l

being pressurized above its Safety Limit of 2750 psia. Each safety valve i

is designed to relieve 420,000 lbs. per hour of saturated steam at the valve setpoint. The relief capacity of a single safety valve is adequate to relieve any overpressure condition which could occur during shutdown.

In the event that no safety valves are OPERABLE, an operating shutdown cooling loop, connected to the RCS,_provides overpressure relief capability and will prevent RCS overpressurization.

During operation, all pressurizer code safety valves must be OPERABLE l

to prevent the RCS from being pressurized above its safety limit of 2750 i

psia.

The combined relief capacity of these valves is sufficient to limit

[

the Reactor Coolant System pressure to within its Safety Limit _of 2750 psia following a complete loss of turbine generator load while operating

.I at RATED THERMAL POWER and assuming no reactor trip until the first i

Reactor Protective System trip setpoint (Pressurizer Pressure-liigh) is i

reached (i.e., no credit is taken for a direct reactor trip on the loss of j

turbine) and also assuming no operation of the steam dump valves.

l f

l ARKANSAS - UNIT 2 B 3/4 4-1 Amendment No. 14, 29 6

j l

• ADMINISTRATIVE CONTROLS 6.7 SAFETY LIMIT VIOLATION l

t 6.7.1 The following actions shall be taken in the event a Safety Limit is violated:

a.

The unit shall be placed.n at Icast HOT STANDBY within one hour.

b.

The Vice President, Operations ANO and the SRC shall be notified within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

c.

The Nuclear Regulatory Commission shall be notified pursuant to 10CFR50.72 and a report submitted pursuant to the requirements F

of 10CFR50.36 and Specification 6.6.

6.8 PROCEDURES l

6.8.1 Written precedures shall be established, implemented and maintained covering the activities referenced below:

i The applicable procedures recommended in Appendix "A" of

(

a.

Regulatory Guide 1.33, Revision 2, February 1978.

b.

Refueling operations.

f c.

Surveillance and test activities of safety related equipment.

d.

Security Plan implementation.

e.

Emergency Plan implementation.

l f.

Fire Protection Program implementation, g.

Modification of Core Protection Calculator (CPC) Addressable Constants.

These procedures should include provisions to assure i

that sufficient margin is maintained in CPC Type I addressable c>nstants to avoid excessive operator interaction with the CPCs j

during reactor operation.

NOTE:

Modifications to the CPC software (including changes of algcrithms and fuel cycle specific data) shall be performed in accordance with the most recent version of "CPC Protection Algorithm Software Change Procedure,"

l CEN-39(A)-P that has been determined to be applicable to the facility. Additions or deletions to CPC addressable i

constants or changes to addressable constant software limit values shall not be implemented without prior NRC approval.

j i

h.

New and spent fuel storage.

i.

ODCM and PCP implementation.

l j.

Postaccident sampling (includes sampling of reactor coolant, j

radioactive iodines and particulates in plant gaseous effluent, and the containment atmosphere).

6.8.2 Each procedure of 6.8.1 above, and changes in intent thereto, shall be reviewed by the PSC and approved by the General Manager, Plant Operations, Plant Manager, AND-2 or responsible Major Department Head l

prior to implementation and reviewed periodically as set forth in administrative procedures.

t ARKANSAS - UNIT 2 6-13 Amendment No. /E,2E,65,52, (E,65,75,77,ET,,71, PE.JZA,119

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