ML13028A066

2012 Point Beach Nuclear Plant Initial License Examination Proposed Written Exam Handouts

ML13028A066
Person / Time
Site:	Point Beach
Issue date:	12/17/2012
From:	NRC/RGN-III
To:
Zoia, Charles
Shared Package
ML11354A219	List: ML13028A065 ML13028A066 ML13028A069 ML13028A070 ML13028A074 ML13035A236
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Download: ML13028A066 (1)

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file:///Gl/...Proposed/Written%20Exam/written%20exam%20references/RO%20Provided%20to%20examinees/Steam%20Table%20Mollier.txt[1/4/2013 8:22:36 AM]

POINT BEACH NUCLEAR PLANT EOP-3 UNIT 1 EMERGENCY OPERATING PROCEDURE SAFETY RELATED Revision 4 3 11/2011 STEAM GENERATOR TUBE RUPTURE Page 28 of 44 lsTEPI ACTION/EXPECTED RESPONSE I I RESPONSE NOT OBTAINED I

CAUTION RCS and ruptured S/G pressures must be maintained less than 1050 psig.

I' " I

• 37 Control RCS Pressure And Charging *

• Flow To Minimize RCS To S/G Leakage: *

• a. Perform appropriate action(s) *

• from table: *

• RUPTURED S/G LEVEL *

• PZR LEVEL *

• RISING LOWERING OFF SCALE HIGH *

• LESS THAN 0 Raise charging Raise charging Raise charging 0 *

• OR EQUAL TO flow flow flow *

• [ 4 4 % ] 24% *

• 0 Depressurize 0 Maintain RCS and *

• RCS using ruptured S/G *

• Step 3 8 pressures equal *

• BETWEEN Depressurize Turn on Maintain RCS and *

• [ 4 4 % ] 24% RCS using PZR heaters ruptured S/G *

• AND 50% Step 3 8 pressures equal *

• BETWEEN 0 Depressurize Turn on Maintain RCS and *

• 50% AND RCS using PZR heaters ruptured S/G *

• [60%1 6 8 % Step 3 8 pressures equal *

• 0 Reduce *

• charging flow *

• GREATER THAN Reduce Turn on PZR Maintain RCS and *

• OR EQUAL TO charging flow heaters ruptured S/G *

• [60%] 68% pressures equal

• 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 A.1 Close or isolate MFIV. 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> inoperable.

AND A.2 Verify MFIV is closed or Once per isolated. 7 days B. One or more MFRVs B.1 Close or isolate MFRV. 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> inoperable.

AND B.2 Verify MFRV is closed Once per or isolated. 7 days C. One or more MFRV C.1 Close or isolate MFRV 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Bypass Valves Bypass Valve inoperable.

AND C.2 Verify MFRV Bypass Once per 7 days Valve is closed or isolated Point Beach 3.7.3-1 Unit 1 - Amendment No. 241 Unit 2 - Amendment No. 245

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

CONDITION REQUIRED ACTION COMPLETION TIME D. Two valves in the same D.1 Isolate affected flow 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> flowpath inoperable. path E. Required Action and E.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time not met. AND E.2 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.3.1 Verify each MFIV, MFRV, and MFRV bypass 18 months valve, actuate to the isolation position on an actual or simulated actuation signal.

SR 3.7.3.2 Verify each MFIV, MFRV, and MFRV Bypass In accordance Valve isolation time is within limits. with the Inservice Testing Program Point Beach 3.7.3-2 Unit 1 - Amendment No. 241 Unit 2 - Amendment No. 245

Rod Group Alignment Limits 3.1.4 3.1 REACTIVITY CONTROL SYSTEMS 3.1.4 Rod Group Alignment Limits LCO 3.1.4 All shutdown and control rods shall be OPERABLE, with individual rod positions within limits.

APPLICABILITY: MODES 1 and 2.

ACTIONS

---

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

One hour is allowed following rod motion prior to verifying rod operability and group alignment limits.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more rod(s) A.1.1 Verify SDM to be within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> inoperable. the limits provided in the COLR.

OR A.1.2 Initiate boration to 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> restore SDM to within limit.

AND A.2 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> (continued)

Point Beach 3.1.4-1 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Rod Group Alignment Limits 3.1.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One rod not within B.1 Restore rod to within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> alignment limits. alignment limits.

OR B.2.1.1 Verify SDM to be within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> the limits provided in the COLR.

OR B.2.1.2 Initiate boration to 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> restore SDM to within limit.

AND B.2.2 Reduce THERMAL 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> POWER to 75% RTP.

AND B.2.3 Verify SDM to be within Once per the limits provided in 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> the COLR.

AND B.2.4 Perform SR 3.2.1.1 and 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> SR 3.2.1.2.

AND B.2.5 Perform SR 3.2.2.1. 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> AND (continued)

Point Beach 3.1.4-2 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Rod Group Alignment Limits 3.1.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.2.6 Re-evaluate safety 5 days analyses and confirm results remain valid for duration of operation under these conditions.

C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Condition B not met.

D. More than one rod not D.1.1 Verify SDM to be within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> within alignment limit. the limits provided in the COLR.

OR D.1.2 Initiate boration to 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> restore required SDM to within limit.

AND D.2 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> Point Beach 3.1.4-3 Unit 1 - Amendment No. 201 Unit 2 - Amendment No. 206

Rod Group Alignment Limits 3.1.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.4.1 Verify individual rod positions are within the 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> following alignment limits:

a. +/- 18 steps of demanded position (as allowed by Table 3.1.4-1) in MODE 1 > 85 percent RTP when bank demand position is < 215 steps; AND

b. +/- 24 steps of demanded position (as allowed by Table 3.1.4-2) in MODE 1 > 85 percent RTP when bank demand position is 215 steps; AND

c. +/- 24 steps of demanded position in MODE 1 85 percent RTP or in MODE 2.

SR 3.1.4.2 Verify rod freedom of movement (trippability) by 92 days moving each rod not fully inserted in the core 10 steps in either direction.

SR 3.1.4.3 Verify rod drop time of each rod, from the fully Prior to reactor withdrawn position, is 2.2 seconds from the criticality after beginning of decay of stationary gripper coil each removal of voltage to dashpot entry, with: the reactor head

a. T avg 500°F; and

b. All reactor coolant pumps operating.

Point Beach 3.1.4-4 Unit 1 - Amendment No. 212 Unit 2 - Amendment No. 217

Rod Group Alignment Limits 3.1.4 Table 3.1.4-1 N

Allowable Alignment Limits As A Function Of Measured Peaking Factor Margin (FQ(Z), FH )

At Power Levels > 85% Of Rated Power And Bank D Demand < 215 Steps Withdrawn ALIGNMENT LIMITS REQUIRED MARGIN TO REQUIRED MARGIN TO N

(STEPS)* FH LIMIT (%) FQ(Z) LIMIT (%)

12 0.00 0.00 13 0.33 0.83 14 0.67 1.67 15 1.00 2.50 16 1.33 3.33 17 1.67 4.17 18 2.00 5.00

• Between the bank demand position and the RPI System.

Table 3.1.4-2 N

Allowable Alignment Limits As A Function Of Measured Peaking Factor Margin (FQ(Z), FH )

At Power Levels > 85% Of Rated Power And Bank D Demand 215 Steps Withdrawn ALIGNMENT LIMITS REQUIRED MARGIN TO REQUIRED MARGIN TO N

(STEPS)* FH LIMIT (%) FQ(Z) LIMIT (%)

12 0.00 0.00 13 0.33 0.83 14 0.67 1.67 15 1.00 2.50 16 1.33 3.33 17 1.67 4.17 18 2.00 5.00 19 2.33 5.83 20 2.67 6.67 21 3.00 7.50 22 3.33 8.33 23 3.67 9.17 24 4.00 10.0

• Between the bank demand position and the RPI System.

Point Beach 3.1.4-5 Unit 1 - Amendment No. 212 Unit 2 - Amendment No. 217

POINT BEACH NUCLEAR PLANT CSP-ST.0 UNIT 1 CRITICAL SAFETY PROCEDURe SAFETY RELATED Revision 6 11/2011 CRITICAL SAFETY FUNCTION STATUS TREES Page 8 of 11 FIGURE 3 S T - 3 HEAT S I N K I

TOTAL NO FEEDWATER

........Q

- FLOW TO SIGs GREATER THAN 230 GPM YES GO TO

• CSP-H.2 NARROW NO NO PRESSURE IN RANGE LEVEL BOTH SIGs

--IIN ANY SIG LESS THAN GREATER THAN 1105 PSlG

[51%] 29% YES YES me*aaa Q 3:;::

NARROW NO RANGE LEVEL IN BOTH SlGs LESS

....o THAN [85%] 91% YES

• CSP-H.4 GO TO NO PRESSURE IN BOTH SlGs LESS THAN 1085 PSlG YES GO TO 1 1 CSP-H.5 NARROW NO RANGE LEVEL IN BOTH SGs GREATER THAN [51%] 29% YES