Text

Safety Evaluation Supporting Amend 41 to License NPF-69
	ML17058B760
Person / Time
Site:	Nine Mile Point
Issue date:	05/10/1993
From:	; Office of Nuclear Reactor Regulation
To:	;
Shared Package
ML17058B759	List: ML17058B758; ML17058B760;
References
	NUDOCS 9305200104
	Download: ML17058B760 (36)
	v • d • e

1

'~p,R RECy, (4

fpO Cy ClO

/p ~**++

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 SAFETY EVALUATION BY THE OFFICE OF NUCLEAR REACTOR REGULATION RELATED TO AMENDMENT NO.

1 TO FACILITY OPERATING LICENSE NO. NPF-69 NIAGARA MOHAWK POWER CORPORATION NINE MILE POINT NUCLEAR STATION UNIT 2 DOCKET NO. 50-410

1. 0 INTRODUCTION By letter dated December 7,

1992, as supplemented March 4,

1993, and April 2,

1993, Niagara Mohawk Power Corporation (the licensee or NMPC) submitted a

request for changes to the Nine Mile Point Nuclear Station, Unit 2 (NMP2),

Technical Specifications (TS).

The requested changes would revise TS Sections 3/4.3, "Instrumentation,"

and 4.4.2. 1, "Safety/Relief Valves-Surveillance Requirements,"

and associated Bases to increase the surveillance test intervals and allowable out-of-service times for various instruments.

The licensee stated in its request that the proposed changes are consistent with the NRC staff's previous approvals of several General Electric Company (GE) Licensing Topical Reports (LTRs).

The licensee's submittal also stated that the proposed out-of-service times are consistent with the guidance provided in NUREG-1434, "Standard Technical Specifications, General Electric

Plants, BWR/6."

The proposed changes would permit specified instrument channel functional tests to be performed quarterly rather than once per week or once per month.

The March 4, 1993, letter clarified the actions to be taken in the event of a loss of more than one instrument channel in a trip system so that a loss of function will not occur.

The March 4, 1993, letter also withdrew the original plant-specific proprietary reports and affidavits requesting withholding of proprietary information.

This letter also resubmitted the plant-specific proprietary reports and affidavits to more specifically delineate GE's proprietary information.

The April 2,

1993, letter clarified and provided bases for operator actions during surveillance and repair of instrument channels.

The March 4,

1993, and April 2,

1993, letters did not change the initial proposed no significant hazards consideration determination.

2. 0 EVALUATION The licensee has proposed changes to TS Sections 3/4.3 and 4.4.2. 1.

The proposed changes are based on the NRC staff's previous approvals of the following GE LTRs:

1.

NEDC-30851P-A, "Technical Specification Improvement Analyses for BWR Reactor Protection System,"

dated March 1988.

This LTR was approved by letter and enclosed safety evaluation dated July 15,

1987, from A. C.

Thadani (NRC) to T. A. Pickens (BWR Owners Group).

9305200104 930510 PDR ADOCK 05000410'

I

2.

NEDC-30851P-A (Supplement 2), "Technical Specification Improvement Analysis for BWR Isolation Instrumentation Common to RPS and ECCS Instrumentation,"

dated March 1989.

This LTR was approved by letter and enclosed safety evaluation dated January 6,

1989, from C.

E. Rossi (NRC) to D.

N. Grace (BWR Owners Group).

3.

NEDC-31677P-A, "Technical Specification Improvement Analysis for BWR Isolation Actuation Instrumentation,"

dated July 1990.

This LTR was approved by letter and enclosed safety evaluation dated June 18,

1990, from C.

E. Rossi (NRC) to S.

D. Floyd (BWR Owners Group).

4.

NEDC-30936P-A, "BWR Owner's Group Technical Specification Improvement Methodology (With Demonstration for BWR ECCS Actuation Instrumentation)

Part 1," dated December 1988.

This LTR was approved by letter and enclosed safety evaluation dated December 9,

1988, from A. C. Thadani (NRC) to D.

N. Grace (BWR Owners Group).

5.

NEDC-30936P-A, "BWR Owner's Group Technical Specification Improvement Methodology (With Demonstration for BWR ECCS Actuation Instrumentation)

Part 2," dated December 1988.

This LTR was approved by letter and enclosed safety evaluation dated December 9,

1988, from C.

E. Rossi (NRC) to D.

N. Grace (BWR Owners Group).

6.

GENE-770-06-2, "Addendum to Bases for Changes to Surveillance Test Intervals and Allowed Out-of-Service Times for Selected Instrumentation Technical Specifications,"

dated February 1991.

This LTR was approved by letter and enclosed safety evaluation dated September 13,

1991, from C.

E.

Rossi (NRC) to G. J.

Beck (BWR Owners Group).

7.

NEDC-30851P-A (Supplement 1), "Technical Specification Improvement Analysis for BWR Control Rod Block Instrumentation,"

dated October 1988.

This LTR was approved by letter and enclosed safety evaluation dated September 22,

1988, from C.

E. Rossi (NRC) to D. N. Grace (BWR Owners Group).

8.

GENE-770-06-1, "Bases for Changes to Surveillance Test Intervals and Allowed Out-of-Service Times for Selected Instrumentation Technical Specifications,"

dated February 1991.

This LTR was approved by letter and enclosed safety evaluation dated July 21,

1992, from C.

E. Rossi (NRC) to

. R.

D. Bing IV (BWR Owners Group).

Each of the above LTRs was prepared and approved on a generic basis with requirements for individual licensees to perform plant-specific evaluations to demonstrate that the LTRs are applicable to plant-specific license amendment requests.

NHPC has performed the required plant-specific evaluations for NMP2.

These evaluations are discussed below:

1.

Appendix L of NEDC-30851P-A identifies

NHP2, a

GE BWR-5 product line reactor with a Hark II containment, as a participating utility in the development of this LTR.

Section 7.4, "Conclusions of Plant Specific

Applications," of NEDC-30851P-A concluded that the generic results of this LTR can be applied to NHP2.

Furthermore, NHPC's December 7,

1992, submittal included a copy of GE Report HDE-78-0485 DRF A00-02119-D, April 1985 (Proprietary),

"Technical Specification Improvement Analysis for the Reactor Protection System for Nine Mile Point, Unit 2," which concludes in Section 4, "Summary and Conclusions," that the generic analysis in NEDC-30851P-A is applicable to NHP2.

Therefore, we have concluded that NEDC-30851P-A is applicable to NHP2.

Appendix A of NEDC-30851P-A (Supplement

2) identifies NHP2 as a

participating utility in the development of this LTR.

Section 3.2 of the LTR specifically analyzes BWR 5/6 plants.

Therefore, we have concluded that NEDC-30851P-A (Supplement

2) is applicable to NHP2.

Appendix E of NEDC-31677P-A identifies NHP2 as a participating utility in the development of this LTR.

Section 5.2 and Appendix C2 of the LTR specifically analyze BWR 5/6 plants.

Therefore, we have concluded that NEDC-31677P-A is applicable to NHP2.

Appendix N of Part 1 of NEDC-30936P-A identifies NHP2 as a participating utility in the development of this LTR.

NHPC's December 7,

1992, submittal included a copy of GE Report RE-026 DRF A00-02558E, February 1987 (Proprietary),

"Technical Specification Improvement Analysis for the Emergency Core Cooling System Actuation Instrumentation for Nine Mile Point Nuclear Station, Unit 2," which concludes in Section 4, "Summary and Conclusions," that the generic analyses in NEDC-30936P-A, Parts 1 and 2, are applicable to NHP2.

Therefore, we have concluded that NEDC-30936P-A, Part 1, is applicable to NHP2.

Appendix B of Part 2 of NEDC-30936P-A identifies NHP2 as a participating utility in the development of this LTR.

Section 5.5 of the LTR specifically analyzes BWR 5/6 plants.

Furthermore, as noted

above, GE Report RE-026 also concludes that the generic analyses in NEDC-30936P-A are applicable to NHP2.

Therefore, we have concluded that NEDC-30936P-A, Part 2, is applicable to NHP2.

GENE-770-06-1 identifies application of changes to surveillance test intervals and allowed out-of-service times for selected instrumentation for all BWR plants.

Therefore, we have concluded that GENE-770-06-1 is applicable to NMP2.

Section 3.2 of GENE-770-06-2 concludes that changes justified by that LTR apply to BWR 5/6 plants.

Therefore, we have concluded that GENE-770-06-2 is applicable to NMP2.

Appendix B of NEDC-30851P-A (Supplement

1) identifies NHP2 as a

participating utility in the development of this LTR.

Section 4 of the LTR specifically addresses BWR-5 plants.

Therefore, we have concluded that NEDC-30851P-A (Supplement

1) is applicable to NHP2.

Each of the above LTRs also contains requirements for licensees to demonstrate that the drift characteristics for the applicable instrumentation are bounded by the assumptions used in the LTRs when the functional test interval is extended from monthly to quarterly.

The licensee has reviewed current drift information provided by the equipment vendors and the applicable setpoint calculations for NHP2 instruments in response to these requirements.

The NHP2 setpoint calculation methodology assumed 18-month trip unit calibration intervals and therefore is not affected by the changes proposed in the licensee's amendment request.

In addition, sensor calibration intervals for the NHP2 instrumentation addressed by the LTRs were verified by NMPC to be equal to or longer than once per quarter and are therefore unaffected by the proposed changes.

The licensee has concluded that the drift characteristics of the involved instrumentation are bounded by the assumptions used in the LTRs when the functional test interval is extended from monthly to quarterly.

The NRC staff agrees with this NHPC conclusion since it is consistent with the clarification regarding instrument drift allowances provided in a letter dated April 27,

1988, from,C.

E. Rossi (NRC) to R. F. Janecek (BWR Owners Group).

NEDC-30851P-A requires NMPC to confirm that the differences between the parts of the Reactor Protection System (RPS) that perform trip functions in NMP2 and those of the base case plant were evaluated in a plant-specific analysis using the procedures of Appendix K of the LTR.

The plant-specific analysis was documented in GE Report HDE-78-0485.

This report utilized the procedures of Appendix K of NEDC-30851P-A to identify and evaluate the RPS differences.

The results of this analysis indicated that while the NHP2 and base case RPS configurations have several differences, the differences do not have a

significant impact on the generic conclusions.

The NRC staff concludes that the licensee has satisfied the requirement of NEDC-30851P-A to evaluate the RPS configuration differences.

NRC staff evaluations of specific proposed changes are as follows:

TS 3 4.3. 1 Reactor Protection S stem RPS Instrumentation Actions a.

and b. for TS 3.3. 1 specify actions to be taken in the event that the number of operable RPS instrumentation channels is less than required by TS Table 3.3. 1-1.

The proposed changes would revise Actions a.

and b. to read:

a.

With one channel required by Table 3.3. 1-1 inoperable in one or more Functional Units, place the inoperable channel and/or that trip system in the tripped condition* within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

The provisions of Specification 3.0.4 are not applicable.

b.

With two or more channels required by Table 3.3. 1-1 inoperable in one or more Functional Units:

1.

Within one hour, verify sufficient channels remain OPERABLE or tripped* to maintain trip capability in the Functional Unit, and

2.

Within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , place the inoperable channel(s) in one trip system and/or that trip system** in the tripped condition*, and 3.

Within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , restore the inoperable channels in the other trip system to an OPERABLE status or tripped*.

Otherwise, take the ACTION required by Table 3.3.1-1 for the Functional Unit.

An inoperable channel or trip system need not be placed in the tripped condition where this would cause the Trip Function to occur.

In these cases, if the inoperable channel is not restored to OPERABLE status within the required time, the ACTION required by Table 3.3. 1-1 for the Functional, Unit shall be taken.

- This ACTION applies to that trip system with the most inoperable channels; if both trip systems have the same number of inoperable

channels, the ACTION can be applied to either trip system.

The proposed changes to Actions a.

and b. for TS 3.3. 1 would increase and clarify the time permitted to place an inoperable RPS instrumentation channel in the tripped condition when the number of operable channels is less than required.

These changes are acceptable since they are consistent with NEDC-30851P-A and with current NRC staff positions and related guidance provided in NUREG-1434 to ensure that a loss of function will not exist if two or more channels are inoperable.

The proposed change to Table Notation (a) on TS Table 3.3. 1-1 would revise the notation to read:

(a)

When a channel is placed in an inoperable status solely for performance of required surveillances, entry into associated Conditions and required ACTIONS may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated function or the redundant function maintains ECCS initiation capability.

The change to Table Notation (a) on TS Table 3.3.1-1 would increase the time permitted for an operable RPS instrumentation channel to be declared inoperable for surveillance purposes without placing the channel in the tripped condition from 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

This proposed change is consistent with the provisions of NEDC-30851P-A and is, therefore, acceptable.

The proposed changes to TS Table 4.3. l. 1-1 would decrease the channel functional test interval requirement for Functional Unit 12, Manual

Scram, from monthly to weekly and would increase the channel functional test interval requirement for the following Functional Units from weekly or monthly to quarterly:

a.

Average Power Range Monitor Flow Biased Simulated Thermal. Power-Upscale (Functional Unit 2.b.)

It

b.

Average Power Range Monitor Fixed Neutron Flux - Upscale (Functional Unit 2.c.)

c.

Average Power Range Monitor Inoperative (Functional Unit 2.d.)

d.

Reactor Vessel Steam Dome Pressure - High (Functional Unit 3.)

e.

Reactor Vessel Water Level - Low, Level 3 (Functional Unit 4.)

f.

Main Steam Line Isolation Valve - Closure (Functional Unit 5.

Ma)n Steam Leone Radlatlon High (Functional Unit 6.)

Drywell Pressure High (Functional Unit 7.)

Scram Discharge Volume Water Level - High, Transmitter Trip Unit (Functional Unit 8.a.)

j.

Scram Discharge Volume Water Level High, Float Switches (Functional Unit 8.b.)

k.

Turbine Stop Valve Closure (Functi'onal Unit 9.)

l.

Turbine Control Valve Fast Closure, Valve Trip System Oil Pressure Low (Functional Unit 10.)

The proposed change to Table Notation (k) on TS Table 4.3.1.1-1 would revise the frequency of certain trip unit setpoint calibrations from at least once per 31 days to at least once per 92 days.

This table notation is applicable to the following Functional Units:

a.

Reactor Vessel Steam Dome Pressure High (Functional Unit 3.)

b.

Reactor Vessel Water Level Low, Level 3 (Functional Unit 4.)

c.

Drywell Pressure High (Functional Unit 7.)

d.

Scram Discharge Volume Water Level - High, Transmitter Trip Unit (Functional Unit 8.a.)

The proposed changes to Table Notation (k) and to TS Table 4.3. 1. 1-1 are consistent with NEDC-30851P-A and MDE-78-0485 and are, therefore, acceptable.

TS 3 4.3.2 Isolation Actuation Instrumentation Actions b.

and c. for TS 3.3.2 specify actions to be taken in the event that the number of operable isolation actuation instrumentation channels is less than the minimum required by Table 3.3.2-1.

The proposed changes would revise Actions b.

and c. to read:

b.

With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip System requirement for one trip

system, either 1.

Place the inoperable channel(s) in the tripped condition within a) 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months for trip functions without an OPERABLE channel

b) 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for trip functions common to RPS Instrumentation, and c) 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months for trip functions not common to RPS Instrumentation or 2.

Take the ACTION required by Table 3.3.2-1.

c.

With the number of OPERABLE channels less than required by the Minimum OPERABLE Channels per Trip System requirement for both trip

systems, 1.

Place the inoperable channel(s) in one trip system in the tripped condition within one hour, and 2.

a)

Place the inoperable channel(s) in the remaining trip system in the tripped condition within 1) 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months for trip functions without an OPERABLE channel 2) 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for trip functions common to RPS Instrumentation, and 3) 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months for trip functions not common to RPS Instrumentation.

or b)

Take the ACTION required by Table 3.3.2-1.

The provisions of Specification 3.0.4 are not applicable.

The proposed changes to Actions b.

and c. for TS 3.3.2 would increase and clarify the time permitted to place an inoperable channel in the tripped condition when the number of operable channels is less than required.

These changes are acceptable since they are consistent with NEDC-30851P-A (Supplement 2) and NEDC-31677P-A and with current NRC staff positions and related guidance provided in NUREG-1434 to ensure that a loss of function will not exist if two or more channels are inoperable.

The proposed change to Table Notation (b) on TS Table 3.3.2-1 would revise the notation to read:

(b)

A channel may be placed in an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for required surveillance without placing the Trip System in the tripped condition provided at least one other OPERABLE channel in the same Trip System is monitoring that parameter.

The proposed change to Table Notation (b) would increase the time permitted for an isolation actuation instrumentation channel to be plac'ed in an inoperable status for surveillance purposes without placing the trip system in the tripped condition from 2 to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

This proposed change in consistent

'j

~

with the provisions of NEDC-30851P-A (Supplement 2) and NEDC-31677P-A and is, therefore, acceptable.

The proposed changes to TS Table 4.3.2.1-1 would increase the channel functional test interval requirement for the following Trip Functions from monthly to quarterly:

a.

Primary Containment Isolation Signals (Trip Function 1.)

b.

Reactor Core Isolation Cooling (RCIC) Isolation Signals (Trip Function 2.)

c.

Secondary Containment Isolation Signals (Trip Function 3.)

The proposed change to Table Notation (a) on TS Table 4.3.2. 1-1 would revise the frequency of certain trip unit setpoint calibrations from at least once per 31 days to at least once per 92 days.

This table notation is applicable to the following isolation signals:

1.

Primary Containment Isolation Signals a.

Reactor Vessel Water Level 1)

Low, Low, Low, Level 1

2)

Low, Low, Level 2

3)

Low, Level 3

b.

Drywell Pressure - High c.

Hain Steam Line 1)

Pressure - Low 2).

Flow High d.

Condenser Vacuum Low e.

Reactor Vessel Pressure High (RHR Cut-in Permissive) 2.

RCIC Isolation Signals a.

RCIC Steam Supply Pressure - Low b.

RCIC Steam Line Flow - High c.

RCIC Turbine Exhaust Diaphragm Pressure High d.

Drywell Pressure

- High e.

RHR/RCIC Steam Flow - High The proposed change to Table Notation (c) on TS Table 4.3.2. 1-1 would revise the frequency of channel functional testing on circuitry associated with the primary containment and RCIC manual isolation pushbuttons from at least once per 31 days to at least once per 92 days.

The proposed changes to TS Table 4.3.2. 1-1 and Table Notations (a) and (c) are consistent with NEDC-30851P-A (Supplement 2) and NEDC-31677P-A and are, therefore, acceptable.

TS 3 4.3.3 - Emer enc Core Coolin S stem Actuation Instrumentation The current Table Notation (a) on TS Table 3.3.3-1 specifies that an emergency core cooling system (ECCS) actuation instrumentation channel may be placed in an inoperable status for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months during periods of required surveillance

I

without placing the trip system in the tripped condition provided at least one other operable channel in the same trip system is monitoring that parameter.

The proposed change to Table Notation (a) would revise the 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

ACTION 30 on TS Table 3.3.3-1 applies to Reactor Vessel Water Level - Low,

Low, Low, Level 1 and Drywell Pressure High instrument channels.

The current ACTION 30 requires that if one channel is inoperable and the number of operable channels is less than required by the minimum operable channels per trip function requirement, the inoperable channel must be placed in the tripped condition within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or the associated system must be declared inoperable.

The proposed change to ACTION 30 would extend the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

ACTION 31 on TS Table 3.3.3-1 applies to Low Pressure Core Spray (LPCS)

Pump Discharge Flow - Low (Bypass),

Low Pressure Coolant Injection (LPCI)

Pump Discharge Flow Low (Bypass),

High Pressure Core Spray (HPCS)

System Flow Rate - Low (Bypass),

and HPCS Pump Discharge Pressure High (Bypass) channels.

The current ACTION 31 requires that if the number of operable channels is less than required by -the minimum operable channels per trip function requirement, the inoperable channel must be placed in the tripped condition within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and restored to operable status within 7 days or the associated system must be declared inoperable.

The proposed change to ACTION 31 would extend the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

ACTION 32 on TS Table 3.3.3-1 applies to LPCS Injection Valve Permissive, LPCI Injection Valve Permissive, LPCI Pump Start Time Delay Relay Normal

Power, LPCI Pump Start Time Delay Relay Emergency

Power, LPCS Pump Start Time Delay Normal

Power, LPCS Pump Start Time Delay Emergency

Power, ADS (Automatic Depressurization System)

Timer, Reactor Vessel Water Level Low, Level 3

(Permissive),

LPCS Pump Discharge Pressure - High (Permissive),

LPCI Pump Discharge Pressure - High (Permissive),

ADS Manual Inhibit, and Reactor Vessel Water Level - High Level 8 channels.

The current ACTION 32 requires that if the number of operable channels is less than required by the minimum oper able channels per trip function requirement, the associated ADS trip system or ECCS must be declared inoperable.

The proposed change to ACTION 32 would provide a

period of 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months before the associated ADS trip system or ECCS must be declared inoperable.

ACTION 33 on TS Table 3.3.3-1 applies to LPCS Injection Valve Permissive and LPCI Injection Valve Permissive channels.

The current ACTION 33 requires that if the number of operable channels is less than required by the minimum operable channels per trip function requirement, the inoperable channel must be placed in the tripped condition with 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

The proposed change to ACTION 33 would extend the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

ACTION 35 on TS Table 3.3.3-1 applies to the ECCS Manual Initiation channels.

The current ACTION 35 requires that if the number of operable channels is less than required by the minimum operable channels per trip function requirement, the inoperable channel must be restored to operable status within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months or the associated ADS valve or ECCS must be declared inoperable.

The proposed

a change to ACTION 35 would extend the 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months to restore an inoperable channel to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

ACTION 36 on TS Table 3.3.3-1 applies to the Reactor Vessel Water Level - Low, Low, Level 2 and Drywell Pressure - High channels that actuate HPCS.

The current ACTION 36 requires that if the number of operable channels is less than required by the minimum operable channels per trip function requirement for one trip system, that trip system must be placed in the tripped condition within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or the HPCS system must be declared inoperable.

The proposed change to ACTION 36 would extend the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

ACTION 37 on TS Table 3.3.3-1 applies to the HPCS Pump Suction Pressure Low (Transfer) and Suppression Pool Water Level - High channels.

The current ACTION 37 requires that if the number of operable channels is less than required by the minimum operable channels per trip function requirement, at least one inoperable,.channel must be placed in the tripped condition within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or the HPCS system must be declared inoperable.

The proposed change to ACTION 37 would extend the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

The proposed changes to TS Table 3.3.3-1 are acceptable since they are consistent with NEDC-30936P-A (Part 2),

RE-026, and with current NRC staff positions and related guidance provided in NUREG-1434 to ensure that a loss of function will not exist if two or more channels are inoperable.

The proposed changes to TS Table 4.3.3. 1-1 would extend the channel functional test interval requirement from monthly to quarterly for the following trip functions:

a.

Division I Trip System (Trip Function A.)

b.

Division II Trip System (Trip Function B.)

c.

Division III Trip System - (Trip Function C.)

Table Notation (a) on TS Table 4.3.3. 1-1 applies to ECCS manual initiation switches and currently requires that all circuitry associated with manual initiation other than the actual manual initiation switches receive a channel functional test at least once per 31 days as part of the circuitry required to be tested for automatic system actuation.

The proposed change to Table Notation (a) would change the 31 days to 92 days.

The proposed change to Table Notation (c) on Table 4.3.3.1-1 would revise the frequency of certain trip unit setpoint calibrations from at least once per 31 days to at least once per 92 days.

This notation is applicable to the following ECCS actuation instrumentation as listed on Table 4.3.3. 1-1:

A.1.

RHR-A LPCI Mode and LPCS S stem a.

Reactor Vessel Water Level Low, Low, Low, Level 1

b.

Drywell Pressure - High c.

LPCS Pump Discharge Flow Low (Bypass) d.

LPCS Injection Valve Permissive

e.

LPCI Injection Valve Permissive j.

LPCI Pump A Discharge Flow Low (Bypass)

A.2.

Automatic De ressurization S stem Tri S stem "A" a.

Reactor Vessel Water Level - Low, Low, Low, Level 1

c.

Reactor Vessel Water Level - Low, Level 3 (Permissive) d.

LPCS Pump Discharge Pressure High (Permissive) e.

LPCI Pump A Discharge Pressure High (Permissive) 8.1.

RHR-B and C

LPCI Mode a.

Reactor Vessel Water Level - Low, Low, Low, Level 1

b.

Drywell Pressure High c.

LPCI Injection Valve Permissive h.

LPCI Pump Discharge Flow Low, Level 3 (Permissive)

B.2.

Automatic De ressurization S stem Tri S stem "B" a.

Reactor Vessel Water Level - Low, Low, Low, Level 1

c.

Reactor Vessel Mater Level Low, Level 3 (Permissive) d.

LPCI Pump (B and C) Discharge Pressure - High (Permissive)

C.l.

~HPCB S

'a ~

b.

c ~

d.

e.f.

g.

Reactor Vessel Water Level - Low, Low, Level 2

Drywell Pressure High Reactor Vessel Water Level - High, Level 8

Pump Suction Pressure - Low (Transfer)

Suppression Pool Mater Level High HPCS System Flow Rate Low (Bypass)

Pump Discharge Pressure - High (Bypass)

The proposed changes to TS Table 4.3.3. 1-1 are consistent with NEDC-30936P-A (Parts 1 and 2) and RE-026 and are, therefore, acceptable.

TS 3 4.3.4 Recirculation Pum Tri Actuation Instrumentation Action b. for TS 3.3.4. 1 currently requires that the inoperable channel(s) be placed in the tripped condition within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months if the number of operable anticipated transient without scram recirculation pump trip (ATWS-RPT) system channels is one less than required by the minimum operable channels per trip system requirement for one or both trip systems.

The proposed change to Action b. would extend the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months period to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

Action c. l. for TS 3.3.4. 1 currently requires that both inoperable channels be placed in the tripped condition within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months if the minimum number of operable ATWS-RPT system channels is two or more less than required by the minimum operable channels per trip system requirement for one trip system and the inoperable channels consist of one reactor vessel water level channel and

E J

one reactor vessel pressure channel.

The proposed change to Action c. l. would extend the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months period to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

The footnote for Action c. 1. currently states that the inoperable channels need not be placed in the tripped condition if this would cause the trip function to occur.

In this case the inoperable channel must be restored to operable status within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months , or the trip system must be declared inoperable.

The proposed change to the footnote for Action c. l. would revise the period of time to restore the inoperable channel to operable status from 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

The footnote on Table 3.3.4. 1-1 currently states that one ATWS-RPT trip system may be placed in an inoperable status for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for required surveillance provided the other trip system is operable.

The proposed change to this footnote would increase the allowable time for surveillance from 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

The proposed changes to TS 3.3.4. 1 and TS Table 3.3.4. 1-1 are consistent with GENE-770-06-1 and are, therefore, acceptable.

The proposed revisions to TS Table 4.3.4. 1-1 would change the channel functional test interval requirement from monthly to quarterly for the following trip functions:

1.

Reactor Vessel Water Level Low, Low, Level 2 (Trip Function 1.)

2.

Reactor Vessel Pressure High (Trip Function 2.)

The footnote on Table 4.3.4. 1-1 applies to all trip functions on the table and currently requires that trip unit setpoint calibrations be performed at least once per 31 days.

The proposed change to this footnote would revise the calibration interval from at least once per 31 days to at least once per 92 days.

The proposed changes to TS Table 4.3.4. 1-1 are consistent with GENE-770-06-1 and are, therefore, acceptable.

Action b. for TS 3.3.4.2 currently requires that the inoperable end-of-cycle recirculation pump trip (EOC-RPT) instrumentation channel(s) be placed in the tripped condition within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months if the number of operable channels is one less than required by the minimum operable channels per trip system requirement for one or both trip systems.

The proposed change to Action b. would extend the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months for placing the inoperable channel(s) in the tripped condition to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

Action c. l. for TS 3.3.4.2 currently requires that both inoperable channels be placed in the tripped condition within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months if the number of operable EOC-RPT channels is two or more less than required by the minimum operable channels per trip system requirement for one trip system and if the inoperable channels consist of one turbine control valve channel and one turbine stop valve channel.

The proposed change to Action c. 1. would extend the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months period to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

~

The proposed change to the first footnote on Table 3.3.4.2-1 would extend the amount of time that an EOC-RPT trip system may be placed in an inoperable status for required surveillance from 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

The proposed changes to TS 3.3.4.2 and TS Table 3.3.4.2-1 are consistent with GENE-770-06-1 and are, therefore, acceptable.

The proposed changes to TS Table 4.3.4.2-1 would revise the channel functional test interval requirement for the following trip functions from monthly to quarterly:

a.

Turbine Stop Valve Closure (Trip Function 1.)

b.

Turbine Control Valve Fast Closure (Trip Function 2.)

The proposed changes to TS Table 4.3.4.2-1 are consistent with GENE-770-06-1 and are, therefore, acceptable.

TS 3 4.3.5 Reactor Core Isolation Coolin S stem Actuation Instrumentation Table Notation (a) on TS Table 3.3.5-1 currently permits a Reactor Core Isolation Cooling (RCIC) system actuation instrument channel to be placed in an inoperable status for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for required surveillance.

The proposed change to Notation (a) would extend the 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

Action 50 on TS Table 3.3.5-1 applies to the Reactor Vessel Water Level Low, Low, Level 2 and Reactor Vessel Water Level High, Level 8 RCIC instrumentation functional units.

Action 50 currently specifies that the inoperable channel(s) and/or that trip system must be placed in the tripped condition within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or the RCIC system must be declared inoperable if the number of operable channels for one trip system is less than required by the minimum operable channels per trip system requirement.

The proposed change to Action 50 would extend the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

Action 51 on TS Table 3.3.5-1 applies to the Pump Suction Pressure Low (Transfer)

RCIC instrumentation functional unit.

Action 51 currently specifies that at least one inoperable channel must be placed in the tripped condition within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or the RCIC system must be declared inoperable if the number of operable channels is less than required by the minimum operable channels per trip system requirement.

The proposed change to Action 51 would extend the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

Action 52 on TS Table 3.3.5-1 applies to the Hanual Initiation RCIC instrumentation functional unit.

Action 52 currently specifies that the inoperable channel must be restored to operable status within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months or the RCIC system must be declared inoperable if the number of operable channels is one less than required by the minimum operable channels per trip system requirement.

The proposed change to Action 52 would extend the 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

I

The proposed changes to TS Table 3.3.5-1 are consistent with GENE-770-06-2 and are, therefore, acceptable.

The proposed changes to TS Table 4.3.5. 1-1 would revise the channel functional test interval requirement for the following RCIC trip functions from monthly to quarterly:

a.

Reactor Vessel Water Level - Low, Low, Level 2 (Trip Function 1.)

b.

Reactor Vessel Water Level High, Level 8 (Trip Function 2.)

c.

Pump Suction Pressure - Low (Transfer)

(Trip Function 3.)

d.

Manual Initiation (Trip Function 4.)

The licensee has also proposed to revise the first and third footnotes on TS Table 4.3.5. 1-1.

The first footnote applies to Trip Functions 1, 2, and 3 and currently requires that trip unit setpoint calibrations be performed at least once per 31 days.

The proposed revision to the first footnote would change the required calibration frequency to at least once per 92 days.

The third footnote applies to the manual initiation trip function and currently requires that all circuitry associated with manual initiation except the actual manual initiation switches receive a channel functional test at least once per 31 days as part of the circuitry required to be tested for automatic system actuation.

The proposed revision to the third footnote would change the 31 days to 92 days.

The proposed changes to TS Table 4.3.5.1-1 are consistent with GENE-770-06-2 and are, therefore, acceptable.

~TS 3 4.3.5 Control Rod Block Instrumentation The licensee has proposed to add a footnote to TS 4.3.6 that would allow a control rod block instrumentation channel to be placed in an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for required surveillance without placing the trip system in the tripped condition, provided at least one other operable channel in the same trip system is monitoring that trip function.

Action 62 on TS Table 3.3.6-1 currently specifies that an inoperable channel must be placed in the tripped condition within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months if the minimum number of operable channels is less than required by the minimum operable channels per trip system requirement.

The proposed revision to Action 62 would change the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

Action 62 applies to the following control rod block trip functions:

a.

Scram Discharge Volume (Trip Function 5.)

b.

Reactor Coolant System Recirculation Flow (Trip Function 6.)

c.

Reactor Mode Switch (Trip Function 7.)

The proposed changes to TS 4.3.6 and TS Table 3.3.6-1 are consistent with GENE-770-06-1 and, therefore, acceptable.

The proposed changes to TS Table 4.3.6-1 would modify the channel functional test interval requirement for the following control rod block trip functions from monthly to quarterly:

a.

Rod Block Monitor (Trip Function 1.)

b.

Average Power Range Monitor (Trip Function 2.)

c.

Scram Discharge Volume (Trip Function 5.)

d.

Reactor Coolant System Recirculation Flow (Trip Function 6.)

The proposed changes to TS Table 4.3.6-1 are consistent with NEDC-30851P-A (Supplement 1) and are, therefore, acceptable.

TS 3 4.3.7 Monitorin Instrumentation The licensee has proposed to add a Table Notation (e) to TS Table 3.3.7. 1-1.

This table notation would apply to the Hain Control Room Ventilation Radiation Monitor channels and permit a single channel to be placed in an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for required surveillance without placing the trip system in the tripped condition, provided at least one other operable channel in the same trip system is monitoring the trip function.

Action 74 on TS Table 3.3.7. 1-1 applies to the Hain Control Room Ventilation Radiation Monitor channels and currently specifies, in part, that the inoperable channel must be placed in the tripped condition within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months if the number of operable channels in one or both trip systems is one less than the required minimum number of operable channels.

The proposed change to Action 74 would extend the 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

The proposed revision to TS Table 4.3.7. 1-1 would change the channel functional test interval requirement for the Hain Control Room Ventilation Radiation Monitors from monthly to quarterly.

The proposed changes to TS Tables 3.3.7. 1-1 and 4.3.7. 1-1 are consistent with GENE-770-06-1 and are, therefore, acceptable.

TS 3 4.3.9 Plant S stems Actuation Instrumentation Table Notation (a) on TS Table 3.3.9-1 currently allows a Reactor Vessel Water - High, Level 8 instrument channel to be placed in an inoperable status for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for required surveillance without placing the trip system in the tripped condition.

The proposed change to this table notation would extend the 2-hour period to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

The proposed change to TS Table 4.3.9.1-1 would revise the channel functional test interval requirement for the Feedwater System/Hain Turbine Trip system (Trip Function 1.) from monthly to quarterly.

The proposed changes to TS Tables 3.3.9-1 and 4.3.9. 1-1 are consistent with GENE-770-06-1 and are, therefore, acceptable.

Q,

~

tl.

~

TS 3 4.4.2 Safet Relief Valves TS 4.4.2. 1 currently requires, in part, that the acoustic monitor for each safety/relief valve be demonstrated operable by performance of a channel functional test at least once per 31 days.

The proposed changes to TS 4.4.2. 1 would require channel functional testing at least once per 92 days.

The proposed changes would also add a third footnote to TS 4.4.2. 1 that would permit an acoustic monitor channel to be placed in an inoperable status for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months for required surveillance without placing the trip system in the tripped condition.

The proposed changes to TS 4.4.2. 1 are consistent with GENE-770-06-1 and are, therefore, acceptable.

The proposed changes would also modify the Bases for TS 3/4.3. 1, 3/4.3.2, 3/4.3.3, 3/4.3.4, 3/4.3.5, 3/4.3.6, 3/4.3.7, 3/4.3.9, and 3/4.4.2 to reference the GE LTRs which justify the above proposed changes and provide bases for operator actions during surveillance and repair of instrument channels.

The NRC staff offers no objection to the proposed Bases changes.

The proposed changes would also modify TS Index pages xvi and xvii to reflect the changes to the Bases.

The conforming, administrative changes to the TS Index pages are acceptable.

3.0 STATE CONSULTATION

In accordance with the Commission's regulations, the New York State official was notified of the proposed issuance of the amendment.

The State official had no comments.

4. 0 ENVIRONMENTAL CONSIDERATION The amendment changes a requirement with respect to installation or use of a facility component located within the restricted area as defined in 10 CFR Part 20 and changes surveillance requirements.

The NRC staff has determined that the amendment involves no significant increase in the amounts, and no significant change in the types, of any effluents that may be released

offsite, and that there is no significant increase in individual or cumulative occupational radiation exposure.

The Commission has previously issued a

proposed finding that the amendment involves no significant hazards consideration, and there has been no public comment on such finding (58 FR 5433).

Accordingly, the amendment meets the eligibility criteria for categorical exclusion set forth in 10 CFR 51.22(c)(9).

Pursuant to 10 CFR 51.22(b) no environmental impact statement or environmental assessment need be prepared in connection with the issuance of the amendment.

y, I

5. 0 CONCLUSION The Commission has concluded, based on the considerations discussed

above, that:

(I) there is reasonable assurance that the health and safety of the public will not be endangered, by operation in the proposed

manner, (2) such activities will be conducted in compliance with the Commission's regulations, and (3) the issuance of the amendment will not be inimical to the common defense and security or to the health and safety of the public.

Principal Contributor:

J.

Henning Date:

May ll, 1993

g

~

Docket No. 50-410 Hr.

B. Ralph Sylvia Executive Vice President, Nuclear Niagara Mohawk Power Corporation 301 Plainfield Road

Syracuse, New York 13212 May 11, 1993

Dear Hr. Sylvia:

SUBJECT:

ISSUANCE OF AMENDMENT FOR NINE MILE POINT NUCLEAR STATION, UNIT 2 (TAC NO. M85168)

The Commission has issued the enclosed Amendment No. 41 to Facility Operating License No. NPF-69 for the Nine Mile Point Nuclear Station, Unit 2.

The amendment consists of changes to the Technical Specifications (TS) in response to your application transmitted by letter dated December 7,

1992, as supplemented March 4,

1993, and April 2, 1993.

The amendment revises TS 3/4.3 and 4.4.2. 1 and associated Bases to increase the surveillance test intervals and allowable out-of-service times for various instruments.

The changes are in accordance with General Electric Company Licensing Topical Reports which have been previously reviewed and approved by the NRC staff.

The allowable out-of service times are consistent with the provisions of NUREG-1434, "Standard Technical Specifications, General Electric

Plants, BWR/6."

The changes permit specified instrument channel functional tests to be performed quarterly rather than weekly or monthly.

A copy of the related Safety Evaluation is enclosed.

A Notice of Issuance will be included in the Commission's next regular biweekly Federal Re<eister notice.

Enclosures:

1.

Amendment No.

41 to NPF-69 2.

Safety Evaluation cc w/enclosures:

See next page Distribution:

See attached sheet Sincerely, Original signed by:

John E. Henning, Project Manager Project Directorate I-1 Division of Reactor Projects - I/II Office of Nuclear Reactor Regulation PDI-1: LA CVo an 0/5 93 PDI-1 PH JHennin

5 OTSB CGrimes 4

<0/93 HICB JWerm el OG 93 PDI-1 D

RACa ra 5

/93 OFFICIAL RECORD COPY

+g ~C3 pp FILENAME: A:iNH285168.AMD

A)

T

~f (i f' V,

2 lk 1 II "1

'P 1'~II

ML17058B760

Contents

Text

3.0 STATE CONSULTATION

Dear Hr. Sylvia:

SUBJECT:

Enclosures:

Navigation menu

ML17058B760

Text

3.0 STATE CONSULTATION

Dear Hr. Sylvia:

SUBJECT:

Enclosures:

Navigation menu

Search