ML20235S633

Errata to Amend 35 to License NPF-29,replacing Tech Spec Pages Affected by Amend

ML20235S633
Person / Time
Site:	Grand Gulf
Issue date:	09/25/1987
From:	NRC
To:
Shared Package
ML20235S637	List: ML20235S633
References
TAC-65511, NUDOCS 8710090073
Download: ML20235S633 (16)

Text

.

1.0 DEFINITIONS The following terms are defined so that unifors intenretation of these specifications may be achieved. The defined tems appear in capitalfred type and shall be applicable throughout these Technical Specifications.

ACTION 1.1 ACTION shall be that part of a Specification which prescribes remedial measures required under designated conditions.

AVERAGE PLANAR EXPOSURE

1. 2 The AVERAGE PLANAR EXPOSURE shall be applicable to a specific planar height and is equal to the sum of the exposure of all the fuel rods in the specified bundle at the specified height divided by the number of fuel rods in the fuel bundle.

. AVERAGE PLANAR LINEAR NEAT GENERATION RATE

1. 3 The AVERAGE PLANAR LINEAR HEAT GENERATIDH RATE (APLHGR) shall be applicable to a specific planar height and is equal to the sum of the LINEAR MEAT GENERATION RATES for all the fuel rods in the specified bundle at the specified height divided by the number of fuel rods in the fuel bundle.

CHANNEL CALIBRATION 1.4 A CHANNEL CALIBRATION shall be the adjustment, as necessary, of the channel output such that it responds with the necessary range and accuracy to known values of the parameter which the channel monitors. The CHANNEL CALIBRATION shall encompass the entire channel including the sensor and alare and/or f. rip functions, and shall include the CHANNEL FUNCTIONAL TEST. The CHANNEL CALIBRATION may be performed by any series of aequential, overlapping or total channel steps such that the antire channel is calibrated.

CHANNEL CNECK 1.5 A CHANNEL CHECK shall be the qualitative assessment of channel behavior during operation by observation. This determination shall include, where i

possible, comparison of the channel indication and/or status with other indi-cations and/or status derived from independent instrument channels measuring the same parameter.

CHANNEL FUNCTIONAL TEST 1.6 A CHANNEL FUNCTIONAL TEST shall be:

Analog channels - the injection of a simulated signal into the-a.

channel as close to the sensor as practicable to verify OPERABILITY including alars and/or trip functions and channel failure trips.

b.

Bu, table channels - the in.iection of a simuisted signal into the sensor te verify OPERABILITY including alars and/or trip functions.

The CHANNEL FUNCTIONAL TEST may be perfomed by any series of seguential, overlapping or total channel steps such that the entire channel is tested.

8710090073 870925 PDR ADOCK 05000416 P

PDR GRAND GULF-UNIT 1 1-1

. _ = _ _

DEFINITIONS CORE ALTERATION 1.7 CORE ALTERATION shall be the addition, removal, relocation or movement of fuel, sources, incore instruments or reactivity controls within the reactor pressure vessel with the vessel head removed and fuel in the vessel.

Normal movement of the SRMs, IRMs, LPRMs, TIPS, or special movable detectors is not considered to be CORE ALTERATION.

Suspension of CORE ALTERATIONS shall not preclude completion of the movement of a component to a safe conservative position.

CRITICAL POWER RATIO 1.8 The CRITICAL POWER RATIO (CPR) shall be the ratio of that power in the assembly which is calculated by application of the XN-3 correlation to cause some point in the assembly to experience boiling transition, divided by the actual assembly operating power.

DOSE EQUIVALENT I-131 1.9 DOSE EQUIVALENT I-131 shall be that concentration of I-131, microcuries per gram, which alone would produce the same thyroid dose as the quantity and isotopic mixture of I-131, 1-132, I-133, I-134, and I-135 actually present.

The thyroid dose conversion factors used for this calculation shall be those listed in Table III of TID-14844, " Calculation of Distance Factors for Power and Test Reactor Sites."

ORYWELL INTEGRITY 1.10 ORYWELL INTEGRITY shall exist when:

a.

All drywell penetrations required to be closed during accident conditions are either:

1.

Capable,of being closed by an OPERABLE drywell automatic isolation, system, or 2.

Closed by at least one manual valve, blind flange, or i

deactivated automatic valve secured in its closed position, except as provided in Table 3.6.4-1 of Specification 3.6.4.

b.

The drywell equipment hatch is closed and sealed.

c.

The drywell airlock is in compliance with the requirements of Specification 3.6.2.3.

d.

The drywell leakage rates are within the limits of Specification 3.6.2.2.

e.

The suppression pool is in compliance with the requirements of Specification 3.6.3.1.

f.

The sealing mechanism associated with each drywell penetration; e.g., welds, bellows or 0-rings, is OPERABLE.

GRAND GULF-UNIT 1 1-2 Amendment No. 35 l

_A

[

4 l

3/4.1 REACTIVITY CONTROL SYSTEMS 3/4.1.1 SHUTDOWN MARGIN LIMITING CONDITION FOR OPERATION 3.1.1 The SHUTDOWN MARGIN shall be equal to or greater than:

a.

0.38% delta k/k with the highest worth rod analytically determined, or 1

b.

0.28% delta k/k with the highest worth rod determined by test.

1 APPLICABILITY:

OPERATIONAL CONDITIONS 1, 2, 3, 4 and 5.

ACTION:

With the SHUTDOWN MARGIN less than specified:

a.

In OPERATIONAL CONDITION 1 or 2, reestablish the required SHUTDOWN MARGIN within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />, b.

In OPERATIONAL CONDITION 3 or 4, immediately verify all insertable' control rods to be inserted and suspend all activities that could reduce the SHUTDOWN MARGIN.

In OPERATIONAL CONDITION 4, establish SECONDARY CONTAINMENT INTEGRITY within 8 hdurs.

c.

In OPERATIONAL CONDITION 5, suspend CORE ALTERATIONS and other I

activities that could reduce the SHUTDOWN MARGIN and insert all insertable control rods within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.

Establish SECONDARY CONTAINMENT INTEGRITY within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />.

SURVEILLANCE REQUIREMENTS 4.1.1 The SHUTDOWN MARGIN shall be determined to be equal to or greater than specified at any time during the fuel cycle:

a.

By measurement, prior to or during the first startup after each refueling.

b.

By measurement, within 500 MWD /T prior to the core average exposure at which the predicted SHUTDOWN MARGIN, including uncertainties and calculation biases, is equal to the specified limit.

c.

Within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after detection of a withdrawn control rod that is immovable, as a result of excessive friction or mechanical interfer-ence, or is untrippable, except that the abe required SHUTDOWN

':reased allowance for MARGIN shall be verified acceptable with c.

the withdrawn worth of the immovable or untr ypable control rod.

GRAND GULF-UNIT 1 3/4 1-1 Amendment No.35

REACTIVITY CONTROL SYSTEMS 3/4.1.2 REACTIVITY ANDELIES LIMIT!NG CvWDITION FOR OPERATION 3.1.2 The reactivity difference between the monitored core k,II and the predicted core k,gg shall not exceed 1% delta k/k.

l APPLICABILITY: OPERATI0 E L CONDITIONS 1 and 2.

AC.T.Lg:

C With the reactivity difference greater ther)15 delta k/k:

I Within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />, perfom an analysis to detami,ne and explain the a.

cause of the reactivity difference; operation any continue if the difference is explained and corrected.

b.

Otherwise', be in at )aast NOT SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

l SURVEILLANCE REQUIREMENTS 4.1.2 The reactivity diffe'rence between the sonitored core k,gg and the predicted core k,ff shall be verified to be lass than or equal to 1% delta k/k:

During the first startup following C0RE ALTERATIONS, and l

a.

b.

At least once per 1000 WD/T during POWER OPERATION.

GRAND GULF-UNIT 1 3/4 1-2 Anemhent No. 23 l

OCT 2 41986

REACTIVITY CONTROL SYSTEMS LIMITING CONDITION FOR OPERATION (Continued)

ACTION:

(Continued) b.

With a " slow" control rod (s) not satisfying ACTION a.1, above:

1.

Declare the " slow" control rod (s) inoperable, and 2.

Perform the Surveillance Requirements of Specification 4.1.3.2.c at least once per 60 days when operation is continued with three or more " slow" control rods declared inoperable.

Otherwise, be in at least HOT SHUTDOWN within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

c.

With the maximum scram insertion time of one or more control rods exceed-ing the maximum scram insertion time limits of Specification 3.1.3.2 as determined by Specification 4.1.3.2.c, operation may continue provided that:

1.

" Slow" control rods, i.e., those which exceed the limits of Specifi-cation 3.1.3 2, do not make up more than 20% of the 10% sample of con-trol rods tested.

2.

Each of these " slow" control rods satisfies the limits of ACTION a.1.

3.

The eight adjacent control rods surrounding each " slow" control rod are:

a)

Demonstrated through measurement within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> to satisfy the maximum scram insertion time limits of Specification 3.1.3.2, and b)

OPERABLE.

4.

The total number of " slow" control rods, as determined by Specifica-tion 4.1.3.2.c, when added to the sum of ACTION a.3, as determined by Specification 4.1.3.2.a and b, does not exceed 7.

j Otherwise, be in at least HOT SHUTDOWN within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

d.

The provisions of Specification 3.0.4 are not applicable.

SURVEILLANCE REQUIREMENTS 4.1.3.2 The maximum insertion time of the control rods shall be demonstrated through measurement with' reactor coolant pressure greater than or equal to 950 psig and, during single control rod scram time tests, the control rod drive pumps isolated from the accumulators:

a.

For all control rods prior to THERMAL POWER exceeding 40% of RATED THERMAL POWER following CORE ALTERATIONS

• or after a reactor shutdown that is greater than 120 days, b.

For specifically affected individual control rods ** following mainten-ance on or modification to the control rod or contr91 rod drive system which could affect the scram insertion time of those specific control rods, and c.

For at least 10% of the control rods, on a rotating basis, at least once per 120 days of POWER OPERATION.

"Except normal control rod movement.

I

• • The provisions of Specification 4.0.4 are not applicable for entry into OPERATIONAL CONDITION 2 provided this surveillance is completed prior to entry into OPERATIONAL CONDITION 1.

GRAND GULF-UNIT 1 3/4 1-7 Amendment No.35 l

REACTIVITY CONTROL SYSTEMS CONTROL ROD SCRAM ACCUMULATORS LIMITING CONDITION FOR OPERATION 3.1.3.3 All control rod scram accumulators shall be OPERABLE:

APPLICABILITY:

OPERATIONAL CONDITIONS 1, 2 and 5*.

ACTION:

a.

It OPERATIONAL CONDITIONS 1 and 2:

1.

With one control rod scram accumulator inoperehle, within 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />s:

a)

Restore the inoperable accumulator to OPERABLE status, or b)

Declare the control rod associated with the inoperable accumulator inoperable.

Otherwise, be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

2.

With more than one control rod scram accumulator inoperable, declare the associated control rods inoperable and:

a)

If the control rod associated with any inoperable scram accumulator is withdrawn, immediately verify that at least one control rod drive pump is operating by inserting at least one withdrawn control rod at least one notch or place the reactor mode switch in the Shutdown position.

b)

Insert the inoperable control rods and disarm the associated directional control valves either:

1)

Electrically, or 2)

Hydraulically by closing the drive water and exhaust water isolation valves.

Otherwise, be in at least HOT SHUTDOWN within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

b.

In OPERATIONAL CONDITION 5*:

1.

With one' withdrawn control rod with its associated scram accumulator inoperable, insert the affected control rod and disarm the associated directional control valves within one hour, either:

a)

Electrically, or b)

Hydraulically by closing the drive water and exhaust water isolation valves.

2.

With more than one withdrawn control rod with the associated scram accumulator inoperable or with no control rod drive pump operating, immediately place the reactor mode switch in the Shutdown position.

The provisions of Specification 3.0.4 are not applicable.

I c.

"At least the accumulator associated with each withdrawn control rod. Not applicable to control rods removed per Specification 3.9.10.1 or 3.9.10.2.

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' INSTRUMENTATION TABLE 3.3.1.1 (Continued) i i

REACTOR PROTECTION SYSTEM INSTRUMENTATION I

ACTION ACTION 1 Be in at least HOT SHUTDOWN within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

ACTION 2 Verify all insertable control rods to be inserted in the core and lock the reactor mode switch in the SHUTDOWN position within one hour.

ACTION 3 Suspend all operations involving CORE ALTERATIONS *, and insert all insertable control rods within one hour.

ACTION 4 Be in at least STARTUP within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

ACTION 5 Be in STARTUP with the main steam line isolation valves closed within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> or in at least HOT SHUTDOWN within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

ACTION C Initiate a reduction in THERMAL POWER'within 15 minutes and reduce turbine first stage pressure to less than the automatic bypass setpoint within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />.

ACTION 7 Verify all insertable control rods to be inserted within one hour.

ACTION 8 Lock the reactor mode switch in the SHUTDOWN position within one hour.

ACTION 9 Suspend all operations involving CORE ALTERATIONS *, and insert all insertable control rods and lock the reactor mode switch in the SHUTDOWN position within one hour.

"Also suspend replacement of LPRM strings unless SRM instrumentation is l

OPERABLE per Specification 3.9.2.

GRAND GULF-UNIT 1 3/4 3-4 Amendment No.35 l

l l

PLANT SYSTEMS BASES 3/4.7.4 SNUBBERS (Continued)

The acceptance criteria are to be used in the visual inspection to determine OPERABILITY of the snubbers.

For example, if a fluid port of a hydraulic snubber is found to be uncovered, the snubber shall be declared inoperable and shall not be determined OPERABLE via functional testing.

l To provide assurance of snubber functional reliability one of three functional testing methsds is used with the stated acceptance criteria:

1.

Functionally test 10% of a type of snubber with an additional 5%

l l

tested for each functional testing failure, or 2.

Functionally test a sample size and determine sample acceptance or rejection using Figure 4.7.4-1, or 3.

Functionally test a representative sample size and determine sample acceptance or rejection using the stated equation.

Figure 4.7.4-1 was developed using "Wald's Sequential Probability Ratio Plan" described in " Quality Control and Industrial Statistics" by Acheson J. Duncan.

Permanent or other exemptions from the surveillance program for individual snubbers may be granted by the Commission if a justifiable basis for exemption is presented and, if applicable, snubber life destructive testing was performed to qualify the snubbers for the applicable design conditions at either the completion of their fabrication or at a subsequent date.

Snubbers so exempted shall be listed in the list of individual snubbers indicating the extent of the exemptions.

The service life of a snubber is established via manufacturer input and information through consideration of the snubber service conditions and asso-ciated installation and maintenance records (newly installed snubber, seal replaced, spring replaced, in high radiation area, in high temperature area, etc.).

The requirement to monitor the snubber service life'is included to ensure that the snubbers periodically undergo a performance evaluation in view of their age and operating conditions. These records will provide statistical bases for future consideration of snubber service life.

3/4.7.5 SEALED SOURCE CONTAMINATION The limitation on removable contamination for sources requiring leak testing, including alpha emitters, is based on 10 CFR 70.39(c) limits for plutonium.

This limitation will e% ure that leakage from byproduct, source, and special nuclear material sources will not exceed allowable intake values.

Scaled sources are classified into three groups according to their use, with surveillance requirements commensurate with the probability of damage to a source in that group.

Those sources which are frequently handled are required to be tested more often than those which are not.

Sealed sources which are continuously enclosed within a shicided mechanism, i.e., sealed sources within radiation monitoring or boron measuring devices, are considered to be stored and need not be tested unless they are removed from the shielded mechanism.

GRAND GULF-UNIT 1 B 3/4 7-3 Amendment No.35 l

______-__a

f PLANT SYSTEMS BASES 3/4.7.6 FIRE SUPPRESSION SYSTEMS The OPERABILITY of the fire suppression systems ensures that adequate fire suppression capability is available to confine and extinguish fires occurring in any portion of the facility where safety-related equipment is located.

The fire suppression system consists of the water system, spray and/or sprinklers, CO2 systems, halon systems and fire hose stations.

The collective capability of the fire suppression systems is adequate to minimize potential damage to safety-related equipment and is a major element in the facility fire protection program.

In the event that portions of the fire suppression systems are inoperable, alternate backup fire fighting equipment is required to be made available in the affected areas until the inoperable equipment is restored to service. When the inoperable fire fighting equipment is intended for use as a backup means of fire suppression, a longer period of time is allowed to provide an alternate

~'means of fire fighting than if the inoperable equipment is the primary means of fire suppression.

The surveillance requirements provide assurances that the minimum OPERABILITY requirements of the fire suppression systems are met.

An allowance is made for ensuring a sufficient volume of halon in the belon storage tanks by verifying the weight and pressure of the tanks.

In the event the fire suppression water system becomes inoperable, immediate corrective measures must be taken since this system provides the major fire suppression capability of the plant.

The surveillance requirements for spray and sprinkler systems provide for periodic visual inspections to ensure that temporary structures / objects do not impair the spray patterns which have been established in accordance with the GGNS fire protection design requirements.

3/4.7.7 FIRE RATED ASSEMBLIES The OPERABILITY of the fire barriers and barrier penetrations ensure that fire damage will be limited.

These design features minimize the possibility of a single fire involving more than one fire area prior to detection and extinguishment.

The fire barriers, fire barrier penetrations for conduits, cable trays and piping, fire windows, fire dampers, and fire doors are periodically inspected to verify their OPERABILITY.

3/4.7.8 AREA TEMPERATURE MONITORING The area temperature limitations ensure taat safety-related equipment will not be subjected to temperatures in excess of their environmental qualification temperatures.

Exposure to excessive temperatures may degrade equipment and can cause loss of its OPERABILITY. The temperature limits include allowance for instrument error.

GRAND GULF-UNIT 1 B 3/4 7-4

PLANT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) e.

Functional Tests During the first refueling shutdown and at least'once per 18 months thereafter during shutdown, a representative sample of snubbers shall be tested using one of the following sample plans for each type of snubber. The sample plan shall be selected prior to the test period j

and cannot be changed during the test period.

The NRC Regional Administrator shall be notified in writing of the sample plan selected prior to the test period or the sample plan used in the prior test period shall be implemented:

1)

At least 10% of the total of each type of snubber shall be functionally tested either in place or in a bench test.

For each snubber of a type that does not meet the functional test acceptance criteria of Specification 4.7.4.f, an additional 5% l of that type of snubber shall be functionally tested until no more failures are found or until all snubbers of that type have been functionally tested; or 2)

A representative sample of each type of snubber shall be func-tionally tested in accordance with Figure 4.7.4-1.

"C" is the total number of snubbers of a type found not meeting the accept-ance requirements of Specification 4.7.4.f.

The cumulative num-ber of snubbers of a type tested is denoted by "N".

At the end of each day's testing, the new values of "N" and "C" (previous day's total plus current day's increments) shall be plotted on i

Figure 4.7.4-1.

If at any time the point plotted falls in the

" Reject" region all snubbers of that type shall be functionally' tested.

If at any time the point plutted falls in the " Accept region, testing of snubbers of that type may be terminated.

When the point plotted lies in the " Continue Testing" region, additional snubbers of that type shall be tested until the point falls in the " Accept" region or the " Reject" region, or all the snubbers of that type have been tested; or 3)

An initial representative sample of 55 snubbers shall be func-tionally tested.

For each snubber type which does not meet the functional test acceptance criteria, another sample of at least one-half the size of the initial sample shall be tested until the total number tested is equal to the initial sample size multi-plied by the factor, 1 + C/2, where "C" is the number of snubbers found which do not meet the functional test acceptance criteria.

The results from this sample plan shall be plotted using an "Ac-cept" line which follows the equation N = 55(1 + C/2).

Each snubber point should be plotted as soon as the snubber is tested.

If the point plotted falls on or below the " Accept" line, testing of that type of snubber may be terminated.

If the point plotted falls above the " Accept" line, testing must continue until the point falls in the " Accept" region or all the snubbers of that j

type have been tested.

l l

GRAND GULF-UNIT 1 3/4 7-11 Amendment No.35l I

4 i

PLANT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued)

Testing equipment failure during functional testing may invalidate that day's testing and allow that day's testing to resume anew at a l

later time, providing all snubbers tested with the failed equipment q

during the day of equipment failure are retested. The representative sample selected for the functional test sample plans shall be ran'domly selected from the snubbers of each type and reviewed before beginning the testing.

The review shall ensure as far as practical that they are representative of the various configurations, operating environ-ments,-range of size, and capacity of snubbers of each type.

Snubbers placed in the same locations as snubbers which failed the previous functional test shall be retested at the time of the next functional test but shall not be included in the sample plan.

If during the functional testing, additional sampling is required due to failure of only one type of snubber, the functional testing results shall be j

reviewed at the time to determine if additional samples should be limited to the type of snubber which has failed the functional testing.

f.

Functional Test Acceptance Criteria l

The snubber functional test shall verify that:

1)

Activation (restraining action) is ach'ieved within the specified-I range in both tension and compression; 2)

Snubber bleed, or release rate where required, is present in both tension and compression, within the specified range; j

3)

For mechanical snubbers, the force required to initiate or main-tain motion of the snubber is within the specified range in both directions of travel; and 4)

For snubbers specifically required not to displace under continuous load, the ability of the snubber to withstand load without displacement.

Testing metho'ds may be used to measure parameters indirectly or parameters other than those specified if those results can be correlated to the specified parameters through established methods.

j g.

Functional Test Failure Analysis An engineering evaluation shall be made of each failure to meet the functional test acceptance criteria to determine the cause of the failure. The results of this evaluation shall be used, if applicable, in selecting snubbers to be tested in an effort to detemine the OPERABILITY of other snubbers irrespective of type which may be subject to the same failure mode.

For the snubbers found inoperable, an engineering evaluation shall l

be performed on the components to which the inoperable snubbers are j

attached. The purpose of this engineering evaluation shall be to deter-j mine if the components to which the inoperable snubbers are attached were adversely affected by the inoperability of the snubbers in order to ensure that the component remains capable of meeting the designed service.

GRAND GULF-L 1

3/4 7-12

REFUELING OPERATIONS 3/4.9.2 INSTRUMENTATION LIMITING CONDITION FOR OPERATION

,3.9.2 At=least 2 source range monitor * (SRM) channels shall be OPERABLE and inserted to the normal operating level with:

a.

Continuous visual: indication in the control room, b.

One of the required SRM detectors located in the' quadrant where CORE ALTERATIONS are being performed and the other required SRM detector located in an adjacent quadrant, and c.

Unless adequate shutdown margin hes been demonstrated, the shorting linksshallberemovedfromtheRPScigcuitrypriortoandduring the time any control rod is withdrawn APPLICABILITY:

OPERATIONAL CONDITION 5.

ACTION:

With the requirements of the above specification not satisfied, immediately suspend all operations involving CORE ALTERATIONS and insert all insertable l

control rods.

SURVEILLANCE REQUIREMENTS 4.9.2 Each of the above required SRM channels shall be demonstrated OPERABLE l

by:

a.

At least once per 12 hour1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />s:

1.

Performance of a CHANNEL CHECK, 2.

Verifying the detectors are inserted to the normal operating I

level, and 3.

During CORE ALTERATIONS, verifying that the detector of an OPER-ABLE SRM channel is located in the core quadrant where CORE l

ALTERATIONS are being performed and another is located in an adjacentquadrant.

"The use of special movable detectors during CORE ALTERATIONS in place of the normal SRM nuclear detectors is permissible as long as these special detectors 1

are connected to the normal SRM circuits.

l

1. ot required for control rods removed per Specification 3.9.10.1 and 3.9.10.2.

N 4

GRAND GULF-UNIT 1 3/4 9-3 Amendment No,35 l

REFUELING OPERATIONS l

SURVEILLANCE REQUIREMENTS (Continued) b.

Performance of a CHANNEL FUNCTIONAL TEST:

1.

Within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> prior to the start of CORE ALTERATIONS, and 2.

At least once per 7 days.

Verifying that the channel count rate is at least 0.7 cps *:

c.

1.

Prior to control rod withdrawal, 2.

Prior to and at least.once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> during CORE ALTERATIONS, and 3.

At least once per 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, I

except that:

1.

During spiral unloading, the required count rate may be permitted to be less than 0.7 cps *.

2.

Prior to and during spiral loading, until sufficient fuel has been loaded to maintain at least 0.7 cps *, the required count rate may be achieved by:

a)

Use of portable external source, or b)

Loading up to 2 fuel assemblies in cells containing inserted control rods around an SRM.

d.

Verifying that the RPS circuitry shorting links" have been removed within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> prior to and at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> during:

The time any control rod is withdrawn," or 1.

2.

Shutdown margin demonstrations.

I i

• Provided signal to noise ratio >2; otherwise use 3 cps.

" Not required for control rods removed per Specification 3.9.10.1 or 3.9.10.2.

These fuel assemblies may be loaded with the SRM count rate less than 0.7 cps.

GRAND GULF-UNIT 1 3/4 9-4

REFUELING OPERATIONS 3/4.9.5 COMMUNICATIONS LIMITING CONDITION FOR OPERATION 3.9.5 Direct communication shall be maintained between the control room and refueling platform personnel.

APPLICABILITY:

OPERATIONAL CONDITION 5, during CORE ALTERATIONS.*

ACTION:

When direct communication between the control room and refueling platform personnel cannot be maintained, immediately suspend CORE ALTERATIONS.*

SURVEILLANCE REQUIREMENTS 4.9.5 Direct communication between the control room and refueling platform personnel shall be demonstrated within one hour prior to the start of and at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> during CORE ALTERATIONS.*

l 1

"Except movement of control rods with their normal drive system.

l l

GRAND GULF-UNIT 1 3/4 9-7 Amendment No. 35l l

_________________A

REFUELING OPERATIONS 3/4.9.6 REFUELING EQUIPMENT REFUELING PLATFORM LIMITING CONDITION FOR OPERATION

'3.9.6.1 The refueling platform shall be OPERABLE and only the main hoist shall be used for handling fuel assemblies.

APPLI'CABILITY:

During handling of fuel assemblies or control rods in the i

primary containment with the refueling platform.

ACTION:

With the requirements for refueling platform OPERABILITY not satisfied, suspend use of any inoperable refueling platform equipment from operations involving the handling of fuel assemblies or control rods after placing the taad in a safe condition.

SURVEILLANCE REQUIREMENTS 4.9.6.1 Each refueling platform hoist to be used for handling fuel assemblies or control rods shall be demonstrated OPERACLE within 7 days prior to the handling of fuel assemblies or control rods:

In the containment fuel pool, reactor cavity or reactor pressure a.

vessel by:

1.

Demonstrating operation of the slack cable cutoff on the main hoist when the total cable load is 50110 pounds.

2.

Demonstrating operation of the grapple engaged loaded interlock on the main hoist before the total cable load exceeds 535 pounds.

3.

Demonstrating operation of the jam cutoff on the main hoist before the total cable load exceeds 1250 pounds.

4.

Demonstrating operation of primary and redundant overload cutoff on the auxiliary hoists before the load exceeds 550 pounds.

i i

b.

In or over the reactor pressure vessel by:

1.

Demonstrating operation of the downtravel cutoff on the main hoist wh'en the bottom of the grapple is 3.5 t 0.5 inches below the top of the fuel assembly handles in the reactor core.

2.

Demonstrating operation of the primary and redundant fuel load interlocks on the main hoist before the total cable load exceeds 600 pounds.

GRAND GULF-UNIT 1 3/4 9-8 a-

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