Text

Technical Specification Pages Extended Power Uprate
	ML110890415
Person / Time
Site:	Point Beach
Issue date:	05/03/2011
From:	Beltz T; Plant Licensing Branch III
To:	; Point Beach
	beltz T, NRR/DORL/LPL3-1, 301-415-3049
Shared Package
ML111170513	List: ML110450159; ML110880039; ML110880682; ML110890415;
References
	TAC ME1044, TAC ME1045
	Download: ML110890415 (24)
	v • d • e

Definitions 1.1 1.1 Definitions RATED THERMAL POWER (RTP)

SHUTDOWN MARGIN (SDM)

SLAVE RELAY TEST STAGGERED TEST BASIS THERMAL POWER RTP shall be a total reactor core heat transfer rate to the reactor coolant of 1800 MWt.

SDM shall be the instantaneous amount of reactivity by which the reactor is subcritical or would be subcritical from its present condition assuming:

a.

All rod cluster control assemblies (RCCAs) are fully inserted except for the single RCCA of highest reactivity worth, which is assumed to be fully withdrawn. However, with all RCCAs verified fully inserted by two independent means, it is not necessary to account for a stuck RCCA in the SDM calculation;

b.

With any RCCA not capable of being fully inserted, the reactivity worth of the RCCA must be accounted for in the determination of SDM; and

c.

In MODES 1 and 2, the fuel and moderator temperatures are changed to the nominal zero power design level.

A SLAVE RELAY TEST shall consist of energizing all slave relays in the channel required for OPERABILITY and verifying the OPERABILITY of each required slave relay.

The SLAVE RELAY TEST shall include a continuity check of associated required testable actuation devices. The SLAVE RELAY TEST may be performed by means of any series of sequential, overlapping, or total channel steps.

A STAGGERED TEST BASIS shall consist of the testing of one of the systems, subsystems, channels, or other designated components during the interval specified by the Surveillance Frequency, so that all systems, subsystems, channels, or other designated components are tested during n Surveillance Frequency intervals, where n is the total number of systems, subsystems, channels, or other designated components in the associated function.

THERMAL POWER shall be the total reactor core heat transfer rate to the reactor coolant.

Point Beach 1.1-5 Unit 1 - Amendment No. 241 Unit 2 - Amendment No. 245

2.0 SLs 2.0 SAFETY LIMITS (SLs) 2.1 SLs 2.1.1 Reactor Core SLs In MODES 1 and 2, the combination of THERMAL POWER, Reactor Coolant System (RCS) highest loop average temperature, and pressurizer pressure shall not exceed the limits specified in the COLR in order to preserve the following fuel design criteria:

2.1.1.1 The departure from nucleate boiling ratio (DNBR) shall be maintained:

1.17 for the WRB-1 correlation

~ 1.30 for the W-3 correlation when system pressure is

> 1000 psia

~ 1.45 for the W-3 correlation when system pressure is

~ 500 psia and ~ 1000 psia 2.1.1.2 The peak fuel centerline temperature shall be maintained

< 5080 of, decreasing by 58 of per 10,000 MWD/MTU of burnup.

2.1.2 RCS Pressure SL In MODES 1, 2, 3, 4, 5, and 6 the RCS pressure shall be maintained

~ 2735 psig.

2.2 SL Violations 2.2.1 If SL 2.1.1 is violated, restore compliance and be in MODE 3 within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

2.2.2 If SL 2.1.2 is violated:

2.2.2.1 In MODE 1 or 2, restore compliance and be in MODE 3 within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

2.2.2.2 In MODE 3, 4, 5, or 6 restore compliance within 5 minutes.

Point Beach 2.0-1 Unit 1 - Amendment No. 241 Unit 2 - Amendment No. 245

3.2.1 Fa(Z)

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued)

AA Perform SR 3.2.1.1 and SR 3.2.1.2.

Prior to increasing THERMAL POWER above the limit of Required Action A.1 B.

NOTE----------

Required Action BA shall be completed whenever this Condition is entered.

F~(Z) not within limits.

8.1 AND B.2 Reduce THERMAL POWER;;::: 1 % RTP for each 1 % F~(Z) exceeds limit.

Reduce Power Range Neutron Flux-High trip setpoints ;;::: 1 % for each 1 % F~(Z) exceeds limits.

4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months 72 hours AND (continued)

Point Beach 3.2.1-2 Unit 1 - Amendment No. 241 Unit 2 - Amendment No. 245

3.2.1 FQ{Z)

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued)

B.3 Reduce the Overpower I:!..T trip setpoints ~ 1 %

for each 1 % F'6(Z) exceeds limits.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AND B.4 Perform SR 3.2.1.1 and SR 3.2.1.2.

Prior to increasing THERMAL POWER above the limit of Required Action B.1.

C.

Required Action and associated Completion Time not met.

C.1 Be in MODE 2.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Point Beach 3.2.1-3 Unit 1 - Amendment No. 241 Unit 2

Amendment No. 245

AFD 3.2.3 3.2 POWER DISTRIBUTION LIMITS 3.2.3 AXIAL FLUX DIFFERENCE (AFD)

LCO 3.2.3 The AFD:

a.

Shall be maintained within the target band about the target flux difference. The target band is specified in the COLR.

b.

May deviate outside the target band with THERMAL POWER

<90% RTP but::.. 50% RTP, provided AFD is within the acceptable operation limits and cumulative penalty deviation time is ~ 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months during the previous 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . The acceptable operation limits are specified in the COLR.

c.

May deviate outside the target band with THERMAL POWER

< 50% RTP.

NOTES-----------------------------------

1.

The AFD shall be considered outside the target band when two or more OPERABLE excore channels indicate AFD to be outside the target band.

2.

With THERMAL POWER::.. 50% RTP, penalty deviation time shall be accumulated on the basis of a 1 minute penalty deviation for each 1 minute of power operation with AFD outside the target band.

3.

With THERMAL POWER < 50% RTP and> 15% RTP, penalty deviation time shall be accumulated on the basis of a 0.5 minute penalty deviation for each 1 minute of power operation with AFD outside the target band.

4.

A total of 16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months of operation may be accumulated with AFD outside the target band without penalty deviation time during surveillance of power range channels in accordance with SR 3.3.1.6, provided AFD is maintained within acceptable operation limits.

APPLICABILITY:

MODE 1 with THERMAL POWER> 15% RTP.

Point Beach 3.2.3-1 Unit 1 - Amendment No. 241 Unit 2 - Amendment No. 245

3.2.3 AFD ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

THERMAL POWER

,::::,,90% RTP.

AND AFD not within the target band A.1 Restore AFD to within target band.

15 minutes B.

Required Action and associated Completion Time of Condition A not met.

B.1 Reduce THERMAL POWER TO <90% RTP.

15 minutes C.

NOTE------------

Required Action C.1 must be completed whenever Condition C is entered.

THERMAL POWER

< 90% and ~ 50% RTP with cumulative penalty deviation time> 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months during the previous 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

OR THERMAL POWER

< 90% and ~ 50% RTP with AFD not within the acceptable operation limits.

C.1 Reduce THERMAL POWER to < 50% RTP.

30 minutes D.

Required Action and associated Completion Time for Condition C not met.

0.1 Reduce THERMAL POWER to < 15% RTP.

9 hours1.041667e-4 days 0.0025 hours 1.488095e-5 weeks 3.4245e-6 months Point Beach 3.2.3-2 Unit 1 - Amendment No. 241 Unit 2 - Amendment No. 245

3.2.3 AFD SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.3.1 Verify AFD within limits for each OPERABLE excore channel.

7 days SR 3.2.3.2 Update target flux difference.

Once within 31 EFPD after each refueling AND 31 EFPD thereafter SR 3.2.3.3

NOTE:---------------------

The initial target flux difference after each refueling may be determined for design predictions.

Determine, by measurement, the target flux difference.

Once within 31 E:FPD after each refueling AND 92 EFPD thereafter Point Beach 3.2.3-3 Unit 1 - Amendment No. 241 Unit 2 - Amendment No. 245

RCS Pressure, Temperature, and Flow DNB Limits 3.4.1 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.1 RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits LCO 3.4.1 RCS DNB parameters for pressurizer pressure, RCS average temperature, and RCS total flow rate shall be within the limits specified below:

a.

Pressurizer pressure is greater than or equal to the limits specified in the COLR;

b.

RCS average temperature is within the limits specified in the COLR; and

c.

RCS total flow rate;;:; 178,000 gpm and greater than or equal to the limit specified in the COLR.

APPLICABILITY: MODE 1.

NOTE------------------------------------

Pressurizer pressure limit does not apply during:

a.

THERMAL POWER ramp> 5% RTP per minute; or

b.

THERMAL POWER step> 10% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

One or more RCS DNB parameters not within limits.

A.1 Restore RCS DNB parameter(s) to within limit.

2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months B.

Required Action and associated Completion Time not met.

B.1 Be in MODE 2.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Point Beach 3.4.1-1 Unit 1 - Amendment No. 241 Unit 2 - Amendment No. 245

3.4.1 RCS Pressure, Temperature, and Flow 01\\18 Limits SURVEILLANCE REQUIREMENTS SR 3.4.1.1 SURVEILLANCE Verify pressurizer pressure is greater than or equal to the limits specified in the COLR.

I::cr:::'QUENCY 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.1.2 Verify RCS average temperature is within the limits specified in the COLR.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.1.3

NOTE-------------------

Not required to be performed until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after

~ 90% RTP.

Verify by precision heat balance that RCS total flow rate is ~ 178,000 gpm and greater than or equal to the limit specified in the COLR.

18 months Point Beach 3.4.1-2 Unit 1 - Amendment No. 241 Unit 2 - Amendment No. 245

Pressurizer 3.4.9 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.9 Pressurizer LCO 3.4.9 The pressurizer shall be OPERABLE with:

a.

Pressurizer water level ~ 52% in MODE 1 or ~ 88% in MODES 2 and 3; and

b.

At least 100 kW of pressurizer heaters capable of being powered from an emergency power supply are OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

Pressurizer water level not within limit in MODE 1.

A.1 Restore pressurizer water level to within limit.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months B.

Required pressurizer heaters inoperable.

B.1 Restore required pressurizer heaters to OPERABLE status.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months C.

Required Action and associated Completion Time not met.

OR Pressurizer water level not within limit in MODES 2 and 3.

C.1 AND C.2 Be in MODE 3.

Be in MODE 4.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months 12 hours Point Beach 3.4.9-1 Unit 1 - Amendment No. 241 Unit 2 - Amendment No. 245

3.4.9 Pressurizer SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.9.1 Verify pressurizer water level is $; 52% in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months MODE 1 OR $; 88% in MODES 2 and 3.

SR 3.4.9.2 Verify capacity of required pressurizer heaters is 92 days

~ 100 kW.

Point Beach Unit 1 - Amendment No. 241 Unit 2 - Amendment No. 245

Pressurizer Safety Valves 3.4.10 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.10 Pressurizer Safety Valves LCO 3.4.10 Two pressurizer safety valves shall be OPERABLE with lift settings

~ 2410 psig and ~ 2547 psig.

APPLICABILITY:

MODES 1, 2, and 3, MODE 4 with all RCS cold leg temperatures> the L TOP enabling temperature specified in the PTLR.

NOTE-------------------------------------

The lift settings are not required to be within the LCO limits during MODES 3 and 4 for the purpose of setting the pressurizer safety valves under ambient (hot) conditions. This exception is allowed for 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months following entry into MODE 3 provided a preliminary cold setting was made prior to heatup.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

One pressurizer safety valve inoperable.

A.1 Restore valve to OPERABLE status.

15 minutes B.

Required Action and associated Completion Time not met.

OR Two pressurizer safety valves inoperable.

8.1 AND B.2 Be in MODE 3.

Be in MODE 4 with any RCS cold leg temperature ~ the L TOP enabling temperature specified in the PTLR.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months 12 hours Point Beach 3.4.10-1 Unit 1 - Amendment No. 241 Unit 2 - Amendment No. 245

Pressurizer Safety Valves 3.4.10 SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.4.10.1 Verify each pressurizer safety valve is OPERABLE in accordance with the Inservice Testing Program. Following testing, lift settings shall be within :t. 1%.

FREQUENCY I n accordance with the Inservice Testing Program Point Beach 3.4.10-2 Unit 1 - Amendment No. 241 Unit 2 - Amendment No. 245

RCS Specific Activity 3.4.16 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C.

Required Action and associated Completion Time of Condition A or B not met.

OR DOSE EQUIVALENT 1-131 >50 pCi/gm.

C.1 AND C.2 Be in MODE 3.

Be in MODE 5.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.16.1

NOTE-------------------------

Only required to be performed in MODE 1.

Verify reactor coolant DOSE EQU IVALENT Xe-133 Specific Activity!: 300 pCi/gm.

7 days SR 3.4.16.2

NOTE-------------------------

Only required to be performed in MODE 1.

Verify reactor coolant DOSE EQUIVALENT 1-131 specific activity ~ 0.5 pCi/gm.

14 days AND Between 2 and 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months after a THERMAL POWER change of ~ 15% RTP within a 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months period Point Beach 3.4.16-2 Unit 1 - Amendment No. 241 Unit 2 - Amendment No. 245

3.5.1 Accumulators SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.1 Verify each accumulator isolation valve is fully open.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.5.1.2 Verify borated water volume in each accumulator is ~ 1100 fe and::; 1136 fe.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.5.1.3 Verify nitrogen cover pressure in each accumulator is ~ 700 psig and::; 800 psig.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.5.1.4 Verify boron concentration in each accumulator is ~ 2700 ppm and::; 3100 ppm.

31 days AND

NOTE-----

Only required to be performed for affected accumulators Once within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after each solution volume increase of

~ 5% of indicated level that is not the result of addition from the refueling water storage tank with boron concentration

~ 2700 ppm and

3100 ppm SR 3.5.1.5 Verify power is removed from each accumulator isolation valve operator when RCS pressure is

> 1000 psig.

31 days Point Beach 3.5.1-2 Unit 1 - Amendment No. 241 Unit 2 - Amendment No. 245

3.5.4 RWST SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.4.1 Verify RWST borated water temperature is

~ 40°F and 5 100°F.

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months SR 3.5.4.2 Verify RWST borated water volume is

~ 275,000 gallons.

7 days SR 3.5.4.3 Verify RWST boron concentration is ~ 2800 ppm and 5 3200 ppm.

7 days Point Beach 3.5.4-2 Unit 1 - Amendment No. 241 Unit 2 - Amendment No. 245

MSSVs 3.7.1 Table 3.7.1-1 (page 1 of 1)

OPERABLE Main Steam Safety Valves versus Maximum Allowable Power NUMBER OF OPERABLE MSSVs PER STEAM GENERATOR 3

2 MAXIMUM ALLOWABLE POWER

(% RTP)

~ 39

~ 22 Point Beach 3.7.1-3 Unit 1 - Amendment No. 241 Unit 2 - Amendment No. 245

MSSVs 3.7.1 Table 3.7.1-2 (page 1 of 1)

Main Steam Safety Valve Lift Settings VALVE NUMBER LIFT SETTING (psig +/- 3%)

A STEAM GENERATOR B

MS 2010 MS 2011 MS 2012 MS 2013 MS 2005 MS 2006 MS 2007 MS 2008 1085 1100 1105 1105 Point Beach 3.7.1-4 Unit 1 - Amendment No. 241 Unit 2 - Amendment No. 245

MFIVs, MFRVs, and MFRV Bypass Valves 3.7.3 3.7 PLANT SYSTEMS 3.7.3 Main Feedwater Isolation Valves (MFIVs), Main Feedwater Regulating Valves (MFRVs) and MFRV Bypass Valves LCO 3.7.3 Main Feedwater Isolation shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3.

ACTIONS

NOTE----------------------------------------------------

Separate Condition entry is allowed for each valve.

CONDITION REQUIRED ACTION COMPLETION TIME A.

One or more MFIVs inoperable.

A. 1 AND A.2 Close or isolate MFIV.

Verify' MFIV is closed or isolated.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Once per 7 days B.

One or more MFRVs inoperable.

B.1 AND B.2 Close or isolate MFRV.

Verify MFRV is closed or isolated.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Once per 7 days C.

One or more MFRV Bypass Valves inoperable.

C.1 AND Close or isolate MFRV Bypass Valve 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months C.2 Verify MFRV Bypass Valve is closed or isolated Once per 7 days Point Beach 3.7.3-1 Unit 1 - Amendment No. 241 Unit 2 - Amendment No. 245

3.7.3 MFIVs, MFRVs, and MFRV Bypass Valves ACTIONS (continued)

COMPLETION TIME REQUIRED ACTION CONDITION 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months flowpath inoperable.

D.1 Isolate affected flow D.

Two valves in the same path 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

E.1 Be in MODE 3.

E.

Required Action and AND 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months E.2 Be in MODE 4.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.3.1 Verify each MFIV, MFRV, and MFRV bypass valve, actuate to the isolation position on an actual or simulated actuation signal.

18 months SR 3.7.3.2 Verify each MFIV, MFRV, and MFRV Bypass Valve isolation time is within limits.

In accordance with the Inservice Testing Program Point Beach 3.7.3-2 Unit 1 - Amendment No. 241 Unit 2 - Amendment No. 245

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.4 CORE OPERATING LIMITS REPORT (COLR) (continued)

(4)

WCAP-14787, Rev 3, "Westinghouse Revised Thermal Design Procedure Instrument Uncertainty Methodology for Point Beach Units 1 & 2 Power Uprate (1775 MWt Core Power with Feedwater Venturis, or 1800 MWt Core Power with LEFM on Feedwater Header)"

(5)

WCAP-10054-P-A, "Westinghouse Small Break ECCS Evaluation Model Using The NOTRUMP Code," August 1985.

(6)

WCAP-10054-P-A, "Addendum to the Westinghouse Small Break ECCS Evaluation Model Using the NOTRUMP Code:

Safety Injection into the Broken Loop and COSI Condensation Model," Addendum 2. Revision 1, July 1997.

(7)

WCAP-8745-P-A. "Design Bases for the Thermal Overpower

~T and Thermal Overtemperature ~T Trip Functions,"

September 1986.

(8)

DELETED (9)

WCAP-10924-P-A, "Large Break LOCA Best Estimate Methodology, Volume 2: Application to Two-Loop PWRs Equipped with Upper Plenum Injection," and Addenda, December 1988. (cores not containing 422 V+ fuel)

(10) WCAP-10924-P-A, "LBLOCA Best Estimate Methodology:

Model Description and Validation: Model Revisions," Volume 1, Addendum 4, August 1990. (cores not containing 422 V+ fuel)

(11) Caldon, Inc., Engineering Report-80P, "TOPICAL REPORT:

Improving Thermal Power Accuracy and Plant Safety While Increasing Operating Power Level Using the LEFM,(TM System,"

Revision 0, March 1997.

(12) Caldon, Inc., Engineering Report-160P, "Supplement to Topical Report R-80P: Basis for a Power Uprate With the LEFM,(TM System," Revision 0, May 2000.

(13) WCAP-16009-P-A, "Realistic Large-Break LOCA Evaluation Methodology Using the Automated Statistical Treatment of Uncertainty Method (ASTRUM)," January 2005.

(14) W CAP-16259-P-A, "Westing house Methodology for Application of 3-D Transient Neutronics to Non-LOCA Analysis,"

August 2006.

(15) WCAP-9403 (nonproprietary), "Power Distribution Control and Load Following Procedures, "Westinghouse Electric Corporation," September 1974.

(16) NS-TMA-2198, Westinghouse to NRC Letter, Attachment "Operation and Safety Analysis Aspects of Improved Load Follow Package," January 31,1980.

(17) NS-CE-687, Westinghouse to NRC Letter, "Power Distribution Control Analysis," July 16, 1975.

Point Beach 5.6-4 Unit 1 - Amendment No. 241 Unit 2 - Amendment No. 245

Reporting Requirements 5.6 5.6 Reporting Requirements

c.

The core operating limits shall be determined such that all applicable limits (e.g., fuel thermal mechanical limits, core thermal hydraulic limits, Emergency Core Cooling Systems (ECCS) limits, nuclear limits such as SDM, transient analysis limits, and accident analysis limits) of the safety analysis are met.

d.

The COLR, including any midcycle revisions or supplements, shall be provided upon issuance for each reload cycle to the NRC 5.6.5 Reactor Coolant System (RCS) PRESSURE AND TEMPERATURE LIMITS REPORT (PTLR)

a.

RCS pressure and temperature limits for heat up, cooldown, low temperature operation, criticality, hydrostatic testing, L TOP enabling, and PORV lift settings as well as heatup and cooldown rates shall be established and documented in the PTLR for the following:

(1) LCO 3.4.3, "RCS Pressure and Temperature (PIT) Limits" (2) LCO 3.4.6, "RCS Loops-MODE 4" (3) LCO 3.4.7, "RCS Loops-MODE 5, Loops Filled" (4) LCO 3.4.10, "Pressurizer Safety Valves" (5) LCO 3.4.12, "Low Temperature Overpressure Protection (L TOP)"

b.

The analytical methods used to determine the RCS pressure and temperature limits shall be those previously reviewed and approved by the NRC, specifically those described in the NRC Letters dated October 6, 2000, July 23, 2001, and October 18, 2007.

c.

The PTLR shall be provided to the NRC upon issuance for each reactor vessel fluence period and for any revision or supplement thereto.

5.6.6 PAM Report When a report is required by Condition B or F of LCO 3.3.3, "Post Accident Monitoring (PAM) Instrumentation," a report shall be submitted within the following 14 days. The report shall outline the preplanned alternate method of monitoring, the cause of the inoperability, and the plans and schedule for restoring the instrUmentation channels of the Function to OPERABLE status.

Point Beach 5.6-5 Unit 1 - Amendment No. 229 Unit 2 - Amendment No. 234

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.7 Tendon Surveillance Report Abnormal conditions observed during testing will be evaluated to determine the effect of such conditions on containment structural integrity. This evaluation should be completed within 30 days of the identification of the condition. Any condition which is determined in this evaluation to have a significant adverse effect on containment structural integrity will be considered an abnormal degradation of the containment structure.

Any abnormal degradation of the containment structure identified during the engineering evaluation of abnormal conditions shall be reported to theNuciear Regulatory Commission pursuant to the requirements of 10 CFR 50.4 within thirty days of that determination. Other conditions that indicate possible effects on the integrity of two or more tendons shall be reportable in the same manner. Such reports shall include a description of the tendon condition, the condition of the concrete (especially at tendon anchorages), the inspection procedure and the corrective action taken.

5.6.8 Steam Generator Tube Inspection Report A report shall be submitted Within 180 days after the initial entry into MODE 4 following completion of an inspection performed in accordance with the Specification 5.5.8, Steam Generator (SG) Program. The report shall include:

a.

The scope of inspections performed on each SG,

b.

Active degradation mechanisms found,

c.

Nondestructive examination techniques utilized for each degradation mechanism,

d.

Location, orientation (if linear), and measured sizes (if available) of service induced indications,

e.

Number of tubes plugged during the inspection outage for each active degradation mechanism,

f.

Total number and percentage of tubes plugged to date,

g.

The results of condition monitoring, including the results of tube pulls and in-situ testing, and

h.

The effective plugging percentage for all plugging in each SG.

Point Beach 5.6-6 Unit 1 - Amendment No. 229 Unit 2 - Amendment No. 234

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.8 Steam Generator Tube Inspection Report (continued)

i.

Following completion of an inspection performed in Unit 1 Refueling Outage 31 (and any inspections performed in the subsequent operating cycle), the number of indications and location, size, orientation, whether initiated on primary or secondary side for each service-induced flaw within the thickness of the tubesheet, and the total of the circumferential components and any circumferential overlap below 17 inches from the top of the tubesheet as determined in accordance with TS 5.5.8,

j.

Following completion of an inspection performed in Unit 1 Refueling Outage 31 (and any inspections performed in the subsequent operating cycle), the primary to secondary LEAKAGE rate observed in each steam generator (if it is not practical to assign leakage to an individual SG, the entire primary to secondary LEAKAGE should be conservatively assumed to be from one steam generator) during the cycle preceding the inspection which is the subject of the report, and

k.

Following completion of an inspection performed in Unit 1 Refueling Outage 31 (and any inspections performed in the subsequent operating cycle), the calculated accident leakage rate from the portion of the tube below 17 inches from the top of the tubesheet for the most limiting accident in the most limiting steam generator.

Point Beach Unit 1 - Amendment No. 234 Unit 2 - Amendment No. 229

v t e Letter Sequence Other
TAC:ME1044, Clarify Application of Setpoint Methodology for LSSS Functions (Approved, Closed) TAC:ME1045, Clarify Application of Setpoint Methodology for LSSS Functions (Approved, Closed)
Initiation Request, Request, Request, Request, Request, Request, Request, Request, Request, Request, Request, Request, Request, Request, Request, Request, Request, Request, Request, Request, Request, Request, Request, Request, Request, Request, Request, Request, Request, Request, Request, Request, Request Acceptance, Acceptance, Acceptance Supplement, Supplement, Supplement, Supplement, Supplement, Supplement, Supplement, Supplement Administration Meeting, Meeting, Meeting, Meeting, Meeting, Meeting, Meeting, Meeting, Meeting Questions 19 July 2010 2 August 2010 2 August 2010 11 August 2010 11 August 2010 31 August 2010 31 August 2010 10 September 2010 10 September 2010 8 November 2010 8 November 2010 20 January 2011 26 August 2009 22 October 2009 22 October 2009 6 November 2009 5 November 2009 16 November 2009 24 November 2009 22 December 2009 13 January 2010 1 February 2010 25 March 2010 31 March 2010 25 March 2010 25 March 2010 9 April 2010 7 April 2010 31 March 2010 1 April 2010 22 April 2010 23 April 2010 19 July 2010 26 August 2010 8 September 2010 8 September 2010 16 September 2010 16 September 2010 4 October 2010 4 October 2010 19 October 2010 19 October 2010 3 November 2010 18 November 2010 23 November 2010 18 November 2010 Answers 13 May 2010 1 June 2009 25 September 2009 21 November 2009 21 November 2009 16 December 2009 20 November 2009 30 November 2009 20 November 2009 21 December 2009 13 January 2010 26 April 2010 29 April 2010 30 April 2010 11 June 2010 9 August 2010 23 August 2010 26 August 2010 27 September 2010 28 September 2010 12 November 2010 12 November 2010 13 December 2010 13 January 2011 Results Approval, Approval, Approval, Approval, Approval, Approval Other: ML092800543, ML102371288, ML102440059, ML102810591, ML102880003, ML102880628, ML110880039, ML110880682, ML110890415, ML111080583
MONTHYEAR2009-04-08 [Table View]

ML110890415

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