Text

Nov/Dec 2002-301 Exam Final Ro/Sro Written Exam Handouts
	ML030560850
Person / Time
Site:	Vogtle
Issue date:	01/10/2003
From:	Ernstes M; Operator Licensing and Human Performance Branch
To:	Gasser J; Southern Nuclear Operating Co
References
	50-424/02-301, 50-425/02-301 50-424/02-301, 50-425/02-301
	Download: ML030560850 (104)
	v • d • e

Final Submittal (Blue Paper)

VOGTLE EXAM 2002-301 50-424 AND 50-425 NOVEMBER 26, &

DECEMBER 2 - 13, 2002 FINAL RO/SRO WRITTEN EXAM HANDOUTS AND PROCTOR NOTES

References

1. 008AK1.01 -

(3cv,-tinx_

Steam Tables

2. 076AA2.02 -_-

0 Tech Spec 3.4.16 "RCS Specific Activity" including figure 3.4.16-1 (Provide the complete section)

3. G2.2.22 Ca-o o-vxi Tech Spec 2.0 "Safety Limits" including figure 2.1.1-1

4. G2.4.11 C-k 18009-C "Steam Generator Tube Leak"

5. 011EA1.04*-P50A 19111-C Steps 5 & 6

6. 055K5.03S5-06R COLR Units 1 & 2 (Remove the RIL curves)

SLs 2.0 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 SLs specified in Figure 2.1.1-1.

2.1.2 RCS Pressure SL In MODES 1, 2, 3, 4, and 5, 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, or 5, restore compliance within 5 minutes.

2.2.3 Within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months notify the NRC Operations Center, in accordance with 10 CFR 50.72.

2.2.4 Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , notify the General Manager-Nuclear Plant and Vice President-Nuclear.

2.2.5 Within 30 days a Licensee Event Report (LER) shall be prepared to the NRC pursuant to 10 CFR 50.73.

and submitted 2.2.6 Operation of the unit shall not be resumed until authorized by the NRC.

Vogtle Units 1 and 2 2.0-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Vogtle Units 1 a SLs 2.0 670 iO NOY OPERATE IN S~

THIS AREA 660 650 D*

2235 psig w

640 aw o

630 0

620 0 -10

-x II2 psig 600 ACCEPT BLE OPERATION 590 T

I 5800 10 20 30 40 50 60 70 80 90 100 110 120 PERCENT OF RATED THERMAL POWER Figure 2.1.1-1 Reactor Core Safety Limits nd 2 2.0-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

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 Ž 2199 psig;

b.

RCS average temperature

592.5 0 F; and

c.

RCS total flow rate -> 384,509 gpm.

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 A.1 Restore RCS DNB 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months parameters not within parameter(s) to within

limits, limit.

B. RCS total flow rate B.1.

Perform SR 3.4.1.4.

7 days degraded.

C.

Required Action and CA Be in MODE 2.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

Vogtle Units I and 2 3.4.1-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS Pressure, Temperature, and Flow DNB Limits 3.4.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.1.1 Verify pressurizer pressure is Ž_ 2199 psig.

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

592.50F.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.1.3 Monitor RCS total flow rate for degradation.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.1.4 NOTE ------------------------------

Not required to be performed until 7 days after

>_ 90% RTP.

Verify by precision heat balance that RCS total 18 months flow rate is Ž 384,509 gpm.

Vogtle Units 1 and 2 3.4.1-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS Minimum Temperature for Criticality 3.4.2 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.2 RCS Minimum Temperature for Criticality LCO 3.4.2 APPLICABILITY:

Each RCS loop average temperature (T3vg) shall be Ž 551OF.

MODE 1, MODE 2 with kff Ž 1.0.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

Tavg in one or more RCS A.1 Be in MODE 3.

30 minutes loops not within limit.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.2.1 Verify RCS Tayg in each loop Ž 551 IF.

Once within 30 minutes and every 30 minutes thereafter when the Tavg - Tef deviation alarm is not reset and any RCS loop Tavg < 561'F Vogtle Units 1 and 2 3.4.2-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS P/T Limits 3.4.3 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.3 RCS Pressure and Temperature (P/T) Limits LCO 3.4.3 APPLICABILITY:

RCS pressure, RCS temperature, and RCS heatup and cooldown rates shall be maintained within the limits specified in the PTLR.

At all times.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

NOTE--------

A.1 Restore parameter(s) to 30 minutes Required Action A.2 within limits.

shall be completed whenever this Condition AND is entered.

A.2 Determine RCS is 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months acceptable for continued Requirements of LCO operation.

not met in MODE 1,2, 3, or 4.

B. Required Action and B.1 Be in MODE 3.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A not AND met.

B.2 Be in MODE 5 with RCS 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months pressure < 500 psig.

(continued)

Vogtle Units 1 and 2 3.4.3-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS P/T Limits 3.4.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C.

NOTE C.1 Initiate action to restore Immediately Required Action C.2 parameter(s) to within shall be completed limits.

whenever this Condition is entered.

AND C.2 Determine RCS is Prior to entering Requirements of LCO acceptable for continued MODE 4 not met any time in other operation.

than MODE 1, 2, 3, or 4.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.3.1 -

NOTE ---------------.------------

Only required to be performed during RCS heatup and cooldown operations and RCS inservice leak and hydrostatic testing.

Verify RCS pressure, RCS temperature, and RCS 30 minutes heatup and cooldown rates are within the limits specified in the PTLR.

Vogtle Units I and 2 3.4.3-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS Loops - MODES 1 and 2 3.4.4 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.4 RCS Loops-MODES 1 and 2 LCO 3.4.4 APPLICABILITY:

Four RCS loops shall be OPERABLE and in operation.

MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

Requirements of LCO A.1 Be in MODE 3.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.4.1 Verify each RCS loop is in operation.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Vogtle Units 1 and 2 3.4.4-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS Loops -

MODE 3 3.4.5 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.5 RCS Loops-MODE 3 LCO 3.4.5 Two RCS loops shall be OPERABLE, and either:

a.

Two RCS loops shall be in operation when the Rod Control System is capable of rod withdrawal; or

b.

One RCS loop shall be in operation when the Rod Control System is not capable of rod withdrawal.

S-..-------

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

All reactor coolant pumps may be de-energized for

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period provided:

a.

No operations are permitted that would cause reduction of the RCS boron concentration; and

b.

Core outlet temperature is maintained at least 10°F below saturation temperature.

APPLICABILITY:

MODE 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

One required RCS loop A.1 Restore required RCS 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable, loop to OPERABLE status.

B. Required Action and B.1 Be in MODE 4.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A not met.

(continued)

Vogtle Units 1 and 2 3.4.5-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS Loops -

MODE 3 3.4.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C.

One required RCS loop C.1 Restore required RCS 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months not in operation, and loop to operation.

reactor trip breakers closed and Rod Control OR System capable of rod withdrawal.

C.2 De-energize all control 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months rod drive mechanisms (CRDMs).

D. Two required RCS loops D.1 De-energize all CRDMs.

Immediately inoperable.

AND OR D.2 Suspend all operations Immediately No RCS loop in involving a reduction of operation.

RCS boron concentration.

AND D.3 Initiate action to restore Immediately one RCS loop to OPERABLE status and operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.5.1 Verify required RCS loops are in operation.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

Vogtle Units 1 and 2 3.4.5-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS Loops -

MODE 3 3.4.5 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.5.2 Verify steam generator secondary side water 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months levels are above the highest point of the steam generator U-tubes for required RCS loops.

SR 3.4.5.3 Verify correct breaker alignment and indicated 7 days power are available to the required pump that is not in operation.

Vogtle Units 1 and 2 3.4.5-3 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS Loops -

MODE 4 3.4.6 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.6 RCS Loops-MODE 4 LCO 3.4.6 APPLICABILITY:

Two loops consisting of any combination of RCS loops and residual heat removal (RHR) loops shall be OPERABLE, and one loop shall be in operation.

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

1.

All reactor coolant pumps (RCPs) and RHR pumps may be de-energized for

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period provided:

a.

No operations are permitted that would cause reduction of the RCS boron concentration; and

b.

Core outlet temperature is maintained at least 1 0°F below saturation temperature.

2.

An RCP shall not be started unless the secondary side water temperature of each steam generator (SG) is < 50°F above each of the RCS cold leg temperatures. With no RCP running, this value is reduced to 25 0F at an RCS temperature of 3501F and varies linearly to 50°F at an RCS temperature of 2000F.

MODE 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

One required RCS loop A.i Initiate action to restore a Immediately inoperable, second loop to OPERABLE status.

AND Two RHR loops inoperable.

(continued)

Vogtle Units 1 and 2 3.4.6-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS Loops -

MODE 4 3.4.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One required RHR loop BA Be in MODE 5.

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months inoperable.

AND Two required RCS loops inoperable.

C.

Both required RCS or C.1 Suspend all operations Immediately RHR loops inoperable, involving a reduction of RCS boron concentration.

OR AND No RCS or RHR loop in operation.

C.2 Initiate action to restore Immediately one loop to OPERABLE status and operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.6.1 Verify one RHR or RCS loop is in operation.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.6.2 Verify SG secondary side water levels are above 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months the highest point of the steam generator U-tubes for required RCS loops.

(continued)

Vogtle Units 1 and 2 3.4.6-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS Loops -

MODE 4 3.4.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.6.3 Verify correct pump breaker alignment and 7 days indicated power are available to the required pump that is not in operation.

Vogtle Units I and 2 3.4.6-3 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS Loops-MODE 5, Loops Filled 3.4.7 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.7 RCS Loops-MODE 5, Loops Filled LCO 3.4.7 APPLICABILITY:

MODE 5 with RCS loops filled.

Vogtle Units 1 and 2 3.4.7-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

One residual heat removal (RHR) loop shall be OPERABLE and in operation, and either:

a.

One additional RHR loop shall be OPERABLE; or

b.

The secondary side water level of at least two steam generators (SGs) shall be above the highest point of the steam generator U tubes.

S-.--------

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

1.

The RHR pump of the loop in operation may be de-energized for

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period provided:

a.

No operations are permitted that would cause reduction of the RCS boron concentration; and

b.

Core outlet temperature is maintained at least 1 0°F below saturation temperature.

2.

One required RHR loop may be inoperable for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing provided that the other RHR loop is OPERABLE and in operation.

3.

No reactor coolant pump shall be started unless the secondary side water temperature of each SG is < 50°F above each of the RCS cold leg temperatures.

4.

All RHR loops may be removed from operation during planned heatup to MODE 4 when at least one RCS loop is in operation.

RCS Loops--MODE 5, Loops Filled 3.4.7 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

One RHR loop A.1 Initiate action to restore a Immediately inoperable, second RHR loop to OPERABLE status.

AND OR Required SGs secondary side water A.2 Initiate action to restore Immediately levels not within limits, required SG secondary side water levels to within limits.

B. Required RHR loops B.1 Suspend all operations Immediately inoperable.

involving a reduction of RCS boron concentration.

OR AND No RHR loop in operation.

B.2 Initiate action to restore Immediately one RHR loop to OPERABLE status and operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.7.1 Verify one RHR loop is in operation.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.7.2 Verify SG secondary side water level is above the 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months highest point of the steam generator U-tubes for the required SGs.

(continued)

Vogtle Units I and 2 3.4.7-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS Loops-MODE 5, Loops Filled 3.4.7 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.7.3 Verify correct breaker alignment and indicated 7 days power are available to the required RHR pump that is not in operation.

Vogtle Units I and 2 3.4.7-3 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS Loops -

MODE 5, Loops Not Filled 3.4.8 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.8 RCS Loops-MODE 5, Loops Not Filled LCO 3.4.8 APPLICABILITY:

MODE 5 with RCS loops not filled.

Vogtle Units 1 and 2 3.4.8-1 Amendment No.

Amendment No.

108 (Unit 1) 86 Unit 2)

Two residual heat removal (RHR) loops shall be OPERABLE and one RHR loop shall be in operation. Each valve used to isolate unborated water sources shall be secured in the closed position.

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

1.

All RHR pumps may be de-energized for

15 minutes when switching from one loop to another provided:

a.

The core outlet temperature is maintained > 10°F below saturation temperature.

b.

No operations are permitted that would cause a reduction of the RCS boron concentration; and

c.

No draining operations to further reduce the RCS water volume are permitted.

2.

One RHR loop may be inoperable for *2 hours for surveillance testing provided that the other RHR loop is OPERABLE and in operation.

3.

Valves in the flowpath from the RMWST, through the chemical mixing tank, to the suction of the charging pumps may be open under administrative control provided the RCS is in compliance with the SHUTDOWN MARGIN requirements of LCO 3.1.1 and the high flux at shutdown alarm is OPERABLE.

(continued)

RCS Loops -

MODE 5, Loops Not Filled 3.4.8 ACTIONS (continued)

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

While this LCO is not met, entry into MODE 5 with RCS loops not filled is not permitted.

Vogtle Units I and 2 3.4.8-2 Amendment No.

Amendment No.

108 (Unit 1) 86 Unit 2)

CONDITION REQUIRED ACTION COMPLETION TIME A.

One RHR loop inoperable.

A.1 Initiate action to restore Immediately RHR loop to OPERABLE status.

B. Required RHR loops B.1 Suspend all operations Immediately inoperable.

involving reduction in RCS boron concentration.

OR AND No RHR loop in operation.

B.2 Initiate action to restore Immediately one RHR loop to OPERABLE status and to operation.

C.

One or more valves used C.1 Initiate action to secure Immediately to isolate unborated water valve(s) in closed sources not secured in position.

closed position.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.8.1 Verify one RHR loop is in operation.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.8.2 Verify correct breaker alignment and indicated power 7 days are available to the required RHR pump that is not in operation.

SR 3.4.8.3 Verify each valve that isolates unborated water 31 days sources is secured in the closed position.

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

92%; and

b.

Two groups of pressurizer heaters OPERABLE with the capacity of each group > 150 kW and capable of being powered from an emergency power supply.

APPLICABILITY:

MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

Pressurizer water level A.1 Be in MODE 3 with 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months not within limit, reactor trip breakers open.

AND A.2 Be in MODE 4.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months B. One required group of B.1 Restore required group of 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months pressurizer heaters pressurizer heaters to inoperable.

OPERABLE status.

C.

Required Action and C.1 Be in MODE 3.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition B not AND met.

C.2 Be in MODE 4.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Vogtle Units 1 and 2 3.4.9-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Pressurizer 3.4.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.9.1 Verify pressurizer water level is

92%.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.9.2 Verify capacity of each required group of 18 months pressurizer heaters is Ž 150 kW.

Vogtle Units 1 and 2 3.4.9-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Pressurizer Safety Valves 3.4.10 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.10 Pressurizer Safety Valves LCO 3.4.10 APPLICABILITY:

Three pressurizer safety valves shall be OPERABLE with lift settings

> 2410 psig and

2510 psig.

MODES 1, 2, and 3.

NOTE The lift settings are not required to be within the LCO limits during MODE 3 for the purpose of setting the pressurizer safety valves under ambient (hot) conditions. This exception is allowed for 54 hours6.25e-4 days 0.015 hours 8.928571e-5 weeks 2.0547e-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 A.1 Restore valve to 15 minutes valve inoperable.

OPERABLE status.

B. Required Action and B.1 Be in MODE 3.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

AND OR B.2 Be in MODE 4.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Two or more pressurizer safety valves inoperable.

Vogtle Units I and 2 3.4.10-1 Amendment No. 98 (Unit 1)

Amendment No. 76 (Unit 2)

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

Vogtle Units 1 and 2 3.4.10-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Pressurizer PORVs 3.4.11 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.11 Pressurizer Power Operated Relief Valves (PORVs)

LCO 3.4.11 APPLICABILITY:

Each PORV and associated block valve shall be OPERABLE.

MODES 1, 2, and 3.

ACTIONS S-------------------------------------------------------

NOTES ------

1.

Separate Condition entry is allowed for each PORV.

2.

LCO 3.0.4 is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A.

One or more PORVs A.1 Close and maintain power 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable and capable to associated block valve.

of being manually cycled.

B. One PORV inoperable B.1 Close associated block 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and not capable of being valve.

manually cycled.

AND B.2 Remove power from 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated block valve.

AND B.3 Restore PORV to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OPERABLE status.

(continued)

Vogtle Units 1 and 2 3.4.11-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Pressurizer PORVs 3.4.11 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C.

One block valve CA Place associated PORV 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable, in manual control.

AND C.2 Restore block valve to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OPERABLE status.

D. Required Action and D.1 Be in MODE 3.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A, B, AND or C not met.

D.2 Be in MODE 4.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months E. Two PORVs inoperable E.1 Close associated block 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and not capable of being valves.

manually cycled.

AND E.2 Remove power from 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated block valves.

AND E.3 Be in MODE 3.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months AND E.4 Be in MODE 4.

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

More than one block F.1 Place associated PORVs 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months valve inoperable, in manual control.

AND (continued)

Vogtle Units 1 and 2 3.4.11-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Pressurizer PORVs 3.4.11 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME F.

(continued)

F.2 Restore one block valve 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months to OPERABLE status.

AND F.3 Restore remaining 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months block valve to OPERABLE status.

G.

Required Action and G.A Be in MODE 3.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition F not AND met.

G.2 Be in MODE 4.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.11.1

NOTE Not required to be performed with block valve closed in accordance with the Required Action of Conditions A, B, or E.

Perform a complete cycle of each block valve.

92 days SR 3.4.11.2 Perform a complete cycle of each PORV.

18 months Vogtle Units 1 and 2 3.4.11-3 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

COPS 3.4.12 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.12 Cold Overpressure Protection Systems (COPS)

LCO 3.4.12 APPLICABILITY:

A COPS shall be OPERABLE with all safety injection pumps incapable of injecting into the RCS and the accumulators isolated and either a or b below.

a.

Two RCS relief valves, as follows:

1.

Two power operated relief valves (PORVs) with lift settings within the limits specified in the PTLR, or

2.

Two residual heat removal (RHR) suction relief valves with setpoints

> 440 psig and

460 psig, or

3.

One PORV with a lift setting within the limits specified in the PTLR and one RHR suction relief valve with a setpoint within specified limits.

b.

The RCS depressurized and an RCS vent of Ž 2.14 square inches (based on an equivalent length of 10 feet of pipe).

MODE 4, MODE 5, MODE 6 when the reactor vessel head is on.

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

1.

Accumulator isolation is only required when accumulator pressure is greater than or equal to the maximum RCS pressure for the existing RCS cold leg temperature allowed by the P/T limit curves provided in the PTLR.

2.

The safety injection pumps are not required to be incapable of injecting into the RCS until 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after entering MODE 4 from MODE 3 provided the temperature of one or more RCS cold legs has not decreased below 3250F.

Vogtle Units 1 and 2 3.4.12-1 Amendment No. 96 (Unit1)

Amendment No. 74 (Unit 2)

COPS 3.4.12 ACTIONS NOTE--------------------------------

1.

While this LCO is not met, entry into MODE 6 with the reactor vessel head on from MODE 6, and entry into MODE 5 from MODE 6 with the reactor vessel head on is not permitted.

2.

With one required PORV inoperable for the purpose of cold overpressure protection, entry into MODE 4 from MODE 3 is permitted provided that RCS temperature is maintained above 2750 F, and, within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months , either: the PORV is restored to OPERABLE status; or, an RHR suction relief valve is placed in service so that the requirements of LCO 3.4.12 are met. Otherwise, the reactor Required Action F.1.

vessel must be depressurized and vented in accordance with CONDITION REQUIRED ACTION COMPLETION TIME A.

One or more safety A.1 Render all safety injection 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months injection pumps capable pumps incapable of injecting of injecting into the RCS.

into the RCS.

B. An accumulator not B.1 Isolate affected accumulator.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months isolated when the accumulator pressure is greater than or equal to the maximum RCS pressure for existing cold leg temperature allowed in the PTLR.

C.

Required Action and C.1 Increase RCS cold leg 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion temperature to > 3500F.

Time of Condition B not met.

OR C.2 Depressurize affected 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months accumulator to less than the maximum RCS pressure for existing cold leg temperature allowed in the PTLR.

D. One required RCS relief D.1 Restore required RCS relief 7 days valve inoperable in valve to OPERABLE status.

MODE 4.

(continued)

Vogtle Units 1 and 2 3.4.12-2 Amendment No.

Amendment No.

108 (Unit 1) 86 (Unit 2)

COPS 3.4.12 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. One required RCS relief E.1 Restore required RCS 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months valve inoperable in relief valve to OPERABLE MODE 5 or 6.

status.

F.

Two required RCS relief F.1 Depressurize RCS and 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months valves inoperable, establish RCS vent size within specified limits.

OR Required Action and associated Completion Time of Condition A, C, D, or E not met.

OR COPS inoperable for any reason other than Condition A, B, D, or E.

Vogtle Units 1 and 2 3.4.12-3 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

COPS 3.4.12 SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.4.12.1 Verify both safety injection pumps are incapable of injecting into the RCS.

FREQUENCY Within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after entering MODE 4 from MODE 3 and prior to the temperature of one or more RCS cold legs decreasing below 325OF AND 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter.

SR 3.4.12.2 Verify each accumulator is isolated.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.12.3 Verify RHR suction valves are open for each 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months required RHR suction relief valve.

SR 3.4.12.4 NOTE---------------

Only required to be performed when complying with LCO 3.4.12.b.

Verify RCS vent size within specified limits.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for unlocked open vent valve(s)

AND 31 days for locked open vent valve(s)

(continued)

Vogtle Units I and 2 3.4.12-4 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

COPS 3.4.12 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.12.5 Verify PORV block valve is open for each 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months required PORV.

SR 3.4.12.6

NOTE Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after decreasing RCS cold leg temperature to

3500F.

Perform a COT on each required PORV, 31 days excluding actuation.

SR 3.4.12.7 Perform CHANNEL CALIBRATION for each 18 months required PORV actuation channel.

Vogtle Units 1 and 2 3.4.12-5 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS Operational LEAKAGE 3.4.13 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.13 RCS Operational LEAKAGE LCO 3.4.13 RCS operational LEAKAGE shall be limited to:

a.

No pressure boundary LEAKAGE;

b.

1 gpm unidentified LEAKAGE;

c.

10 gpm identified LEAKAGE;

d.

I gpm total primary to secondary LEAKAGE through all steam generators (SGs); and

e.

500 gallons per day primary to secondary LEAKAGE through any one SG.

APPLICABILITY:

MODES 1, 2,3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

RCS LEAKAGE not A.1 Reduce LEAKAGE to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months within limits for reasons within limits.

other than pressure boundary LEAKAGE.

B. Required Action and B.1 Be in MODE 3.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A not AND met.

B.2 Be in MODE 5.

36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR Pressure boundary LEAKAGE exists.

Vogtle Units 1 and 2 3.4.13-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS Operational LEAKAGE 3.4.13 SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.4.13.1 NOTE-------------

1.

Not required to be performed in MODE 3 or 4 until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months of steady state operation.

2.

Only required to be performed during steady state operation.

Perform RCS water inventory balance.

FREQUENCY Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after achieving steady state operation AND 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months thereafter SR 3.4.13.2 Verify steam generator tube integrity is in In accordance with the accordance with the Steam Generator Tube Steam Generator Tube Surveillance Program.

Surveillance Program Vogtle Units 1 and 2 3.4.13-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS PIV Leakage 3.4.14 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.14 RCS Pressure Isolation Valve (PIV) Leakage LCO 3.4.14 APPLICABILITY:

Leakage from each RCS PIV shall be within limit.

MODES 1, 2, and 3, MODE 4, except valves in the residual heat removal (RHR) flow path when in, or during the transition to or from the RHR mode of operation.

ACTIONS S--

- - - - - - - - - - N O T E S --------------------

1.

Separate Condition entry is allowed for each flow path.

2.

Enter applicable Conditions and Required Actions for systems made inoperable by an inoperable PIV.

CONDITION REQUIRED ACTION COMPLETION TIME A.

One or more flow paths -------------------- NOTE with leakage from one or Each valve used to satisfy Required more RCS PIVs not Action A.1 and Required Action A.2 within limit, must have been verified to meet SR 3.4.14.1 and be in the reactor coolant pressure boundary or the high pressure portion of the system.

(continued)

Vogtle Units 1 and 2 3.4.14-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS PIV Leakage 3.4.14 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

(continued)

A.1 Isolate the high pressure 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months portion of the affected system from the low pressure portion by use of one closed manual, deactivated automatic, or check valve.

AND A.2 Isolate the high pressure 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months portion of the affected system from the low pressure portion by use of a second closed manual, deactivated automatic, or check valve.

B. Required Action and B.1 Be in MODE 3.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time for Condition A not AND met.

B.2 Be in MODE 5.

36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months C.

RHR System suction C.1 Isolate the affected 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months isolation valve penetration by use of one interlock function closed manual or inoperable, deactivated automatic valve.

Vogtle Units 1 and 2 3.4.14-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS PIV Leakage 3.4.14 SURVEILLANCE REQUIREMENTS NOTES ---------------------------

1.

Not required to be performed in MODES 3 and 4.

2.

Not required to be performed on the RCS PIVs located in the RHR flow path when in the shutdown cooling mode of operation.

3.

RCS PIVs actuated during the performance of this Surveillance are not required to be tested more than once if a repetitive testing loop cannot be avoided.

Verify leakage from each RCS PIV is equivalent to

0.5 gpm per nominal inch of valve size up to a maximum of 5 gpm at an RCS pressure

Ž 2215 psig and < 2255 psig.

FREQUENCY In accordance with the Inservice Testing Program, and 18 months AND Prior to entering MODE 2 whenever the unit has been in MODE 5 for 7 days or more, if leakage testing has not been performed in the previous 9 months (except for valves HV 8701ANB and HV 8702AB)

AND (continued)

Vogtle Units I and 2 3.4.14-3 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

SR 3.4.14.1 SURVEILLANCE

RCS PIV Leakage 3.4.14 SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.4.14.1 (continued)

FREQUENCY For systems rated at less than 50% RCS design pressure, within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months following valve actuation (except for valves HV-8701A/B and HV-8702A/B).

SR 3.4.14.2 Verify RHR System suction isolation valve 18 months interlock prevents the valves from being opened with a simulated or actual RCS pressure signal

Ž>

450 psig.

Vogtle Units 1 and 2 3.4.14-4 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS Leakage Detection Instrumentation 3.4.15 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.15 RCS Leakage Detection Instrumentation LCO 3.4.15 APPLICABILITY:

The following RCS leakage detection instrumentation shall be OPERABLE:

a.

The containment normal sumps level and reactor cavity sump monitors;

b.

One containment atmosphere radioactivity monitor (gaseous or particulate); and

c.

Either the containment air cooler condensate flow rate or a containment atmosphere gaseous or particulate radioactivity monitoring system not taken credit for in item b.

MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

One containment sump --------

NOTE monitor inoperable.

LCO 3.0.4 is not applicable.

A.1 Perform SR 3.4.13.1.

Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months B. Two or more

.NOTE containment sump LCO 3.0.4 is not applicable.

monitors inoperable --

B.1 Perform SR 3.4.13.1 Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months AND B.2 Restore at least two 30 days containment sump monitors to OPERABLE status.

(continued)

Vogtle Units 1 and 2 3.4.15-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS Leakage Detection Instrumentation 3.4.15 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C.

Required containment

NOTE----------

atmosphere radioactivity LCO 3.0.4 is not applicable.

m onitor(s) inoperable.

C.1.1 Analyze grab samples of Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months the containment atmosphere.

OR C.1.2 Perform SR 3.4.13.1.

Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months AND C.2.1 Restore required 30 days containment atmosphere radioactivity monitor(s) to OPERABLE status.

OR C.2.2 Verify containment air 30 days cooler condensate flow rate monitor is OPERABLE.

D. Required containment DA Perform SR 3.4.15.2.

Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months air cooler condensate flow rate monitor OR inoperable.

D.2 Perform SR 3.4.13.1.

Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months (continued)

Vogtle Units I and 2 3.4.15-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS Leakage Detection Instrumentation 3.4.15 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E.

Required containment E.1 Restore required 30 days atmosphere radioactivity containment atmosphere monitor inoperable, radioactivity monitor to OPERABLE status.

AND OR Required containment air cooler condensate E.2 Restore required 30 days flow rate monitor containment air cooler inoperable, condensate flow rate monitor to OPERABLE status.

F.

Required Action and F.1 Be in MODE 3.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

AND F.2 Be in MODE 5.

36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months G.

All required leakage G.1 Enter LCO 3.0.3.

Immediately detection systems inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.15.1 Perform CHANNEL CHECK of containment 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months normal sumps level and reactor cavity sump level monitors.

(continued)

Vogtle Units 1 and 2 3.4.15-3 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS Leakage Detection Instrumentation 3.4.15 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.15.2 Perform CHANNEL CHECK of the required 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months containment atmosphere radioactivity monitor.

SR 3.4.15.3 Perform COT of the required containment 92 days atmosphere radioactivity monitor.

SR 3.4.15.4 Perform CHANNEL CALIBRATION of the 18 months containment sump monitors.

SR 3.4.15.5 Perform CHANNEL CALIBRATION of the 18 months required containment atmosphere radioactivity monitor.

SR 3.4.15.6 Perform CHANNEL CALIBRATION of the 18 months required containment air cooler condensate flow rate monitor.

Vogtle Units 1 and 2 3.4.15-4 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS Specific Activity 3.4.16 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.16 RCS Specific Activity LCO 3.4.16 APPLICABILITY:

The specific activity of the reactor coolant shall be within limits.

MODES 1 and 2, MODE 3 with RCS average temperature (Tv,) Ž 5001F.

ACTIONS LCO 3.0.4 is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A.

DOSE EQUIVALENT A.1 Verify DOSE Once per4 hours 1-131 > 1.0 pCi/gm.

EQUIVALENT 1-131 within the acceptable region of Figure 3.4.16-1.

AND A.2 Restore DOSE 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months EQUIVALENT 1-131 to within limit.

B. Gross specific activity of B.1 Perform SR 3.4.16.2.

4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months the reactor coolant not within limit.

AND B.2 Be in MODE 3 with 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Tvg < 5000F.

(continued)

Vogtle Units I and 2 3.4.16-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS Specific Activity 3.4.16 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C.

Required Action and C.1 Be in MODE 3 with 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Tayg < 5000F.

Time of Condition A not met.

OR DOSE EQUIVALENT 1-131 in the unacceptable region of Figure 3.4.16-1.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.16.1 Verify reactor coolant gross specific 7 days activity

lOO/E pgCi/gm.

SR 3.4.16.2 NOTE -------

Only required to be performed in MODE 1.

Verify reactor coolant DOSE EQUIVALENT 1-131 14 days specific activity

1.0 gCi/gm.

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 (continued)

Vogtle Units 1 and 2 3.4.16-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS Specific Activity 3.4.16 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE SR 3.4.16.3 NOTE------

Not required to be performed until 31 days after a minimum of 2 effective full power days and 20 days of MODE 1 operation have elapsed since the reactor was last subcritical for Ž 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months .

Determine E from a sample taken in MODE 1 after a minimum of 2 effective full power days and 20 days of MODE 1 operation have elapsed since the reactor was last subcritical for > 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months .

FREQUENCY 184 days Vogtle Units 1 and 2 3.4.16-3 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

1

RCS Specific Activity 3.4.16 250 200 150 100 50 01 20 30 40 50 60 70 80 90 100 PERCENT OF RATED THERMAL POWER FIGURE 3.4.16-1 REACTOR COOLANT DOSE EQUIVALENT 1-131 REACTOR COOLANT SPECIFIC ACTIVITY LIMIT VERSUS PERCENT OF RATED THERMAL POWER WITH THE REACTOR COOLANT SPECIFIC ACITVITY >1 mCi/gram DOSE EQUIVALENT 1-131 Vogtle Units 1 and 2 3.4.16-4 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

UNACCEPTABLE OPERATION ACCEP ABLE OPER ION

ApprovalProcedure No.

Aro. Gasser Vogtle Electric Generating PlantP 18009-C NUCLEAR OPERATIONS Revision No.

S20 Date 5/10/01 UnitSCOMMON-Page No.

1 of 24 Abnormal Operating Procedures STEAM GENERATOR TUBE LEAK PURPOSE PRB REVIEW REQUIRED Section A of this procedure is the entry point.

It provides operator actions as a result of a confirmed Steam Generator Tube Leak (SGTL)that may require a controlled plant shutdown.

Section B of this procedure is entered from Section A and specifies actions to be taken while operating with a minor SGTL.

SYMPTOMS/ENTRY CONDITIONS ARP 17100 upon indication of a Steam Generator Tube Leak Report from Chemistry of secondary activity Leakage in excess of Technical Specification LCO 3.4.13 Secondary specific activity in excess of Technical Specification LCO 3.7.16 Any of the following symptoms:

PRZR level lowering.

Charging flow higher than normal.

Unexplained/unexpected rise in VCT makeup frequency.

Steam flow greater than feed flow with constant SG level.

-AND Confirmation of increasing radiation levels indicated on one or more of the following PERMS channels:

Primary to Secondary Leak Monitors (RE-0724, RE-0810)

Condenser Air Ejector and Steam Packing Exhauster (RE-12839C)

SGBD Process Monitor (RE-00019)

SGBD Effluent Monitor (RE-00021)

Main Steam Line (RE-13119, RE-13120, RE-13121, RE-13122)

PROCEDURE NO.

IREVISION NO.

VEGP 18009-C 20 2 of 24 A

OPERATION WITH A CONFIRMED TUBE LEAK REQUIRING PLANT SHUTDOWN ACTION/EXPECTED RESPONSE IMMEDIATE OPERATOR ACTIONS Al. Control charging to the normal charging path and letdown to maintain PRZR level and pressure:

a.

Adjust FV-0121 and HV-0182 to maximize charging.

CAUTION:

RESPONSE NOT OBTAINED Al.

IF the unit is in Mode 1 or 2 or Mode 3 greater than 1000 psig AND PRZR level or pressure cannot be maintained, THEN trip the reactor and go to 19000-C, E-0 REACTOR TRIP OR SAFETY INJECTION.

b.

Start an additional charging pump if required.

SUBSEOUENT OPERATOR ACTIONS A2.

Reduce letdown to 45 GPM by initiating 13006, CHEMICAL AND VOLUME CONTROL SYSTEM, if required.

Only one CCP should be operated at a time if the NCP is in service due to limited miniflow cooling capacity.

PROCEDURE NO.

REVISION NO.

PAGE NO.

VEGP 18009-C 20 3 of 24 A

OPERATION WITH A CONFIRMED TUBE LEAK REQUIRING PLANT SHUTDOWN ACTION/EXPECTED RESPONSE NOTE:

RESPONSE NOT OBTAINED A3. Determine if unit shutdown is required:

a.

Check leakrate within the following limits:

1) Leakrate <5 gpm as determined by

[charging-(letdown+

seal leakoff)]

mismatch.

1) CONFIRM the leak rate is due to SG tube leakage by observing higher than normal radiation on at least one of the following radiation monitors (Ref:

Att A, Large Tube Leak):

RE-0724 RE-0810 RE-12839C RE-0019 RE-0021 IF confirmed, THEN a)

Shutdown to Mode 3 within hour using 18013-C RAPID POWER REDUCTION.

b)

Continue with Step A4.

1/2>

"* RCS degas should be initiated if cooldown to Mode 5 is anticipated.

"* The need for additional personnel and resources should be evaluated when commencing unit shutdown due to steam generator tube leakage.

I

PROCEDURE NO.

RVSO O

PG O

VEGP 18009-C j

20 4 of 24 A

OPERATION WITH A CONFIRMED TUBE LEAK REQUIRING PLANT SHUTDOWN ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED (Step 3 continued from previous page)

2)

Leak <150 gpd.

2)

Be in Mode 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months by immediately initiating a shutdown per 12004-C, POWER OPERATION (MODE 1)

(Ref:

Att A Action Level 3)

Continue with Step A4.

3)

Leakrate <75 gpd.

3)

LF 30 minutes after entering this procedure the rate of change of leakage is continuing to increase or has stabilized at a rate greater than or equal to 30 gpd/hr, THEN Reduce power to <50% within one hour per 18013-C, RAPID POWER REDUCTION AND be in Mode 3 within the next 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months . (Ref: Att A Action Level 3)

Continue with Step A4.

IF leakrate has remained

75 gpd for one hour, THEN be in Mode 3 within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months per 12004-C, POWER OPERATION (MODE 1).

(Ref:

Att A Action Level 2)

Continue with Step A4.

I

PROCEDURE NO.

j REVISION NO.

PAGE NO.

VEGP 18009-C 20 5 of 24 A

OPERATION WITH A CONFIRMED TUBE LEAK REQUIRING PLANT SHUTDOWN ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED (Step 3 continued from previous page)

4)

Operations management has determined that the SG tube leakage does not warrant a unit shutdown.

4)

LF Operations management determines that a unit shutdown is warranted:

a)

Initiate a shutdown to Mode 3 per 12004-C, POWER OPERATION (MODE 1).

b)

Continue with Step A4.

b.

Go to Section B of this procedure.

I

PROCEDURE NO.

REVISION NO.

IPAGE NO.

VEGP 18009-C j

20 6 of 24 A

OPERATION WITH A CONFIRMED TUBE LEAK REQUIRING PLANT SHUTDOWN ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED A4. Direct Chemistry and HP to sample for specific activity in the following locations and commence actions as defined in 49009-C, HP/CHEMISTRY STEAM GENERATOR TUBE LEAK ACTIONS.

As a result, CHEMISTRY will:

Sample all SGs.

Sample TPCW downstream of SGBD Trim Heat Exchanger.

"* Perform a radiological release assessment per 36024-C RELEASE PERMIT CONTROLS FOR MAIN STEAM RELEASES DURING PERIODS OF PRIMARY TO SECONDARY LEAKAGE if it is necessary to operate the TDAFW pump (preferably before starting the pump.)

HP will:

Monitor for secondary activity.

A5. Identify the leaking SG by one or more of the following during shutdown, if possible:

SG level with relatively lower feedflow rate STABLE or RISING.

Radiation monitor on a main steamline - HIGH or ALARMING.

"* Portable radiation survey of blowdown lines

- HIGH ACTIVITY.

"* SG activity sample analyses - HIGH ACTIVITY.

PROCEDURE NO.

REVISION NO.

PAGE NO.

VEGP 18009-C 20 7 of 24 A

OFPERATION WITH A CONFIRMED TUBE LEAK REQUIRING PLANT SHUTDOWN ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED CAUTION:

Secondary Water S*

limited and a sept maintained to prel unaffected unit's cleanup.

NOTE:

91001-C EMERGE!

AND IMPLEMENTII implemented at

HP and Chemist SJAE and SPE e A6. Minimize secondary system and environmental contamination by performing the following as conditions require:

,stems inventories should be Lration between the units should be rent contamination of the secondary systems and limit NCY CLASSIFICATION NG INSTRUCTIONS should be this time.

ry should be notified when routing xhaust through HEPA filters.

Dispatch an operator to place SJAE and SPE filtration units in filter mode per 13310, TURBINE BUILDING HVAC SYSTEM.

Panel PTHV:

UNIT 1 (TB-1-TG17)

UNIT 2 (TB-1-TG4)

PROCEDURE NO.

R ISION NO.

PG ofO.

"VEGP 18009-C 20 8 of 24 A

OPERATION WITH A CONFIRMED TUBE LEAK REQUIRING PLANT SHUTDOWN ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED (Step 6 continued from previous page)

Isolate CSTs from the hotwell:

Place LIC-4415 in MANUAL and adjust to obtain 50% demand signal.

"* Verify LV-4415A SHUT:

UNIT 1 (TB-A-THi5)

UNIT 2 (TB-A-TH6)

Dispatch an operator to shut at least one Condensate Dump Valve Manual Isolation Valve:

"* UNIT 1 1-1305-U4-042 (TB-A-TH15)

-OR 1-1305-U4-043 (TB-A-THI5)

"* UNIT 2 2-1305-U4-042 (TB-A-TH6)

-OR 2-1305-U4-043 (TB-A-TH6)

Prepare to transfer and process Turbine Building Drain Tank contents per

13211, TURBINE BUILDING DRAIN SYSTEM, as required.

Place HS-0877 in the RECIRC position to route turbine building sump effluent to the turbine building drain tanks.

1/2*>

I

PROCEDURE NO.

REVISION NO.

PAGE NO.

VEGP 18009-C 20 9 of 24 A

OPERATION WITH A CONFIRMED TUBE LEAK REQUIRING PLANT SHUTDOWN ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED (Step 6 continued from previous page)

NOTE:

Hotwell level may be read at local site glasses LG-4303, LG-4304, and LG-4305 on north side of condensers if control room instrument LIC-4415 is offscale high.

Control hotwell level to maintain less than or equal to 10 inches above normal operating level by draining to the Turbine Building sumps.

Consult with Chemistry and HP to determine and initiate actions required prior to draining potentially contaminated water to the Turbine Building sumps.

Route drain hoses from the following HDP NPSH VALVE INLET DRAIN valves to sumps and throttle as necessary to maintain hotwell level:

"* 1305-X4-895 (HDP A)

"* 1305-X4-896 (HDP A)

"* 1305-X4-898 (HDP B)

"* 1305-X4-899 (HDP B)

Operate the condensate polishing demineralizers as recommended by Chemistry.

IPROCEURE NO.

REVISION NO.

PAGE NO.

VEGP 18009-C 201 10 of 24 A

OPERATION WITH A CONFIRMED TUBE LEAK REQUIRING PLANT SHUTDOWN ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED (Step 6 continued from previous page)

Switch steam loads to aux steam:

"* Pressurize AUX STEAM HEADER from other unit.

"* Switch loads to auxiliary steam by initiating 13761, AUXILIARY STEAM SYSTEM.

PROCEDURE NO.

REVISION NO.

PAGE NO.

VEGP 18009-C 20 11 of 24 A

OPERATION WITH A CONFIRMED TUBE LEAK REQUIRING PLANT SHUTDOWN ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED A7. Maintain VCT level using A7.

If VCT level cannot be automatic or manual makeup maintained, shift charging

control, suction to the RWST:

a.

Open RWST TO CCP A&B SUCTION VALVES:

"* LV-0112D

"* LV-0112E

b.

Shut VCT OUTLET ISOLATION valves:

"* LV-0112B

"* LV-0112C

c.

Align RV TO RWST ISOLATION valves:

HV-8508A CCP-A ENABLE PTL

HV-8508B CCP-B ENABLE PTL

d.

Shut Charging normal mini flow valves:

"* HV-8110 CCP-A&B COMMON MINIFLOW

"* HV-8111A CCP-A MINIFLOW

"* HV-8111B CCP-B MINIFLOW

e.

Verify VCT diverts to HUT on HI level (97%).

PROCEDURE NO.

REVISION NO.

PAGE NO.

VEGP 18009-C 20 12 of 24 A

OPERATION WITH A CONFIRMED TUBE LEAK REQUIRING PLANT SHUTDOWN ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED CAUTION:

Use of SG ARVs should be avoided to preclude a potential radioactive release to the environment.

A8. Verify the following conditions:

a.

Reactor -

SHUTDOWN

b.

RCS temperature - AT OR LESS THAN 5570 F.

C.

Leaking SG -

IDENTIFIED

c.

CONTINUE efforts to identify leaking SG per Steps A4 and A5.

WHEN leaking SG is identified, THEN continue with Step A9.

PROCEDURE NO.

REVISION NO.

PAGE NO.

VEGP 18009-C 20 13 of 24 A

OPERATION WITH A CONFIRMED TUBE LEAK REQUIRING PLANT SHUTDOWN ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED NOTE:

Reference should be made to the table for valve numbers.

A9.

Isolate the leaking SG.

"* Shut blowdown valve(s).

"* Raise SG ARV setpoint to 1160 psig.

(Pot setting approximately 7.73)

"* Shut steam supply to TDAFW pump, if applicable.

"* Shut both MSIVs.

"* Shut MSIV bypass valves.

"* Shut MFIV.

"* Shut MFIV bypass valve.

"* Shut AFW valves.

VALVE NAME SG 1 SG 2 SG 3 SG-4 Blowdown Valve HV-7603A HV-7603B HV-7603C HV-7603D Steam Supply to TDAFW Pump HV-3009 HV-3019 N/A N/A SG ARV PV-3000 PV-3010 PV-3020 PV-3030E MSIV HV-3006A HV-3016A HV-3026A HV-3036A HV-3006B HV-3016B HV-3026B HV-3036B MSIV BYPASS HV-13005A HV-13007A HV-13008A HV-13006A Valves HV-13005B HV-13007B HV-13008B HV-13006B HV-13005C HV-13007C HV-13008C HV-13006C MFIV HV-5227 HV-5228 HV-5229 HV-5230 MFIV BYPASS Valve HV-15196 HV-15197 HV-15198 HV-15199 SG AFW HV-5122 HV-5125 HV-5127 HV-5120 HV-5139 HV-5132 HV-5134 HV-5137

PROCEDURE NO.

REVISION NO.

PAGE NO.

VEGP 18009-C 20 14 of 24 A

OPERATION WITH A CONFIRMED TUBE LEAK REOUIRING ACTION/EXPECTED RESPONSE PLANT SHUTDOWN RESPONSE NOT OBTAINED A10.

Sample TPCW system and verify radioactivity within allowable limits.

All. Maintain RCS temperature using steam dumps.

A12. Maintain SG NR level using MDAFW pumps:

a.

Maintain intact SG(s)

AT 65%.

b.

Maintain leaking SG(s)

GREATER THAN 10%.

NOTE: [

Steps 13 thru A10.

Isolate TPCW to SGBD Trim Hx:

UNIT 1

"* 1-HV-6796 (AB-B03)

"* 1-HV-6795 (AB-B03 UNIT 2

2-HV-6796 (AB-B124) 2-HV-6795 (AB-B124)

Bypass flow to the SGBD Trim HX and reduce SGBD flow to maintain SGBD temperature per 13605, STEAM GENERATOR BLOWDOWN PROCESSING SYSTEM.

All. Maintain RCS temperature using SG ARVs on the non-leaking SGs.

A13. Start RCS cooldown to 500 0 F by initiating 12006-C, UNIT COOLDOWN TO COLD SHUTDOWN.

15 should be performed expeditiously.

Cooldown rate to 500 0 F shall not exceed 1000 F/HR.

PROCEDURE NO.

REVISION NO.

PAGE NO.

VEGP 18009-C 20 15 of 24 A

OPERATION WITH A CONFIRMED TUBE LEAK REOUIRING PLANT SHUTDOWN ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED A14. Verify affected SG ARV SHUT.

A14. IF affected SG pressure less than 1160 psig, THEN shut SG ARV.

NOTE:

During depressurization, at least 50 0 F of RCS subcooling should be maintained.

A15.

WHEN RCS temperature reaches 5000F, THEN depressurize the RCS to 25-50 psig greater than the pressure of the leaking SG per 12006-C, UNIT COOLDOWN TO COLD SHUTDOWN.

NOTE:

RCS pressure should be maintained between psig above the leaking SG pressure to prevent flow from the SG to the RCS.

The cooldown rate shall not exceed 1000F/HR.

25-50 A16. Maintain RCS cooldown and depressurization while observing the following:

Maintain RCS pressure BETWEEN 25 AND 50 PSIG GREATER THAN THE LEAKING SG PRESSURE.

Cooldown to at least Mode 5 as necessary to support corrective actions for repair and secondary decontamination.

PROCEDURE NO.

REVISION NO.

rPA1E NO.

VEGP 18009-C 20 16 of 24 A

OPERATION WITH A CONFIRMED TUBE LEAK REQUIRING PLANT SHUTDOWN ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED A17.

Monitor leaking SG level.

Place SG Blowdown in service as required per

13605, STEAM GENERATOR BLOWDOWN PROCESSING SYSTEM to maintain leaking SG level on scale.

CAUTION:

SGBD flow should not be dumped to the WWRB while using it to cool a leaking SG.

A18. Cool down leaking SG:

a.

Feed with AFW and cycle level between 43% and 81% NR.

b.

Maximize blowdown flow from leaking SG.

PROCEDURE NO.

REVISION NO.

PAGE NO.

VEGP 18009-C 20 17 of 24 A

OPERATION WITH A CONFIRMED TUBE LEAK REQUIRING PLANT SHUTDOWN ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED A19. Evaluate long term plant status:

a.

Consult TSC for subsequent recovery actions.

b.

Maintain the condensate system on long cycle recirculation per

13615, CONDENSATE AND FEEDWATER SYSTEM.

c.

Per Chemistry direction, place the condensate demineralizers in service per 13616, CONDENSATE DEMINERALIZER SYSTEM to aid in secondary plant cleanup.

d.

Contaminated resin should be processed in accordance with 13618, CONDENSATE SPENT RESIN PROCESSING SYSTEM.

e.

Contaminated resin should be transferred in accordance with

13223, SECONDARY SPENT RESIN PROCESSING.

f.

Monitor levels in the Secondary Systems for need to process contaminated inventory.

END OF SUB-PROCEDURE TEXT

PROCEDURE NO.

REVISION NO.

PAGE NO.

VEGP 18009-C 201 18 of 24 B

OPERATION WITH A MINOR TUBE LEAK ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED BI. Monitor RCS leak rate:

Initiate RCS leakrate calculations using 14905, RCS LEAKAGE CALCULATION (INVENTORY BALANCE).

Direct Chemistry and HP to commence actions as defined in 49009-C, HP/CHEMISTRY STEAM GENERATOR TUBE LEAK ACTIONS.

As a result, CHEMISTRY will:

Sample all SGs.

Sample TPCW downstream of SGBD Trim Heat Exchanger.

Quantify leak rate.

, Identify leaking SG.

Perform a radiologicall release assessment per 36024-C RELEASE PERMIT CONTROLS FOR MAIN STEAM RELEASES DURING PERIODS OF PRIMARY TO SECONDARY LEAKAGE if it is necessary to operate the TDAFW pump (preferably before starting the pump.)

HP will:

0 Monitor for secondary activity.

PROCEDURE NO.

REVISION NO.

jPAGE NO.

VEGP 18009-C 20 j

19 of 24 B

OPERATION WITH A MINOR TUBE LEAK ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED B2. Minimize secondary system and environmental contamination by performing the following:

a.

Place the SJAE/SPE filtration units in filter mode per 13310, TURBINE BUILDING HVAC SYSTEM.

Panel PTHV UNIT 1 (TB1-TB17)

UNIT 2 (TBI-TG4)

b.

Isolate CSTs from the hotwell:

"* Place LIC-4415 in MANUAL and adjust to obtain 50% demand signal.

"* Verify LV-4415A SHUT:

UNIT 1 (TB-A-THI5)

UNIT 2 (TB-A-TH6)

b.

Dispatch an operator to shut at least one Condensate Dump Valve Manual Isolation Valve:

UNIT 1 1-1305-U4-042 (TB-A-THI5)

-OR 1-1305-U4-043 (TB-A-TH15)

& UNIT 2 2-1305-U4-042 (TB-A-TH6)

-OR 2-1305-U4-043 (TB-A-TH6)

c.

Operate the condensate polishing demineralizers as recommended by Chemistry.

d.

Place HS-0877 in the RECIRC position to route turbine sump effluent to the turbine building drain tanks.

I I I

PROCEDURE wO.

REVISION NO.

PAGE NO.

VEGP 18009-C 201 20 of 24 B

OPERATION WITH A MINOR TUBE LEAK ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED (Step 2 continued from previous page)

e.

Switch steam loads to aux steam:

Pressurize AUX STEAM HEADER from other unit.

Switch loads to auxiliary steam by initiating 13761, AUXILIARY STEAM SYSTEM.

f.

Control hotwell level to maintain less than or equal to 10 inches above normal operating level by draining to the Turbine Building sumps.

1) Route drain hoses from the following HDP NPSH VALVE INLET DRAIN valves to sumps and throttle as necessary to maintain hotwell level:

"* 1305-X4-895 (HDP A)

"* 1305-X4-896 (HDP A)

"* 1305-X4-898 (HDP B)

"* 1305-X4-899 (HDP B)

PROCEDURE NO.

REVISION NO.

PAGE NO.

VEGP 18009-C 20 21 of 24 B

OPERATION WITH A MINOR TUBE LEAK ACTION/EXPECTED RESPONSE NOTE:

B3. Monitor primary to secondary leakage using RE-0724 and RE-0810.

RESPONSE NOT OBTAINED B3.

IF unable to monitor primary-to-secondary leakage using RE-0724 or RE-0810 on the Plant Computer or PDC:

a.

IF leakrate is stable, THEN ensure Chemistry samples SGs at a minimum of every four hours, and trend the results.

Continue with Step B4.

b.

IF the leakrate is unstable or increasing, THEN be in Mode 3 within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months per 12004-C, POWER OPERATION (MODE 1)

Go to Step A4.

B4. Refer to ATTACHMENT A for definitions and actions corresponding to primary to secondary leakrate.

B5. Control blowdown flow from the affected SG per 13605, STEAM GENERATOR BLOWDOWN as requested by Chemistry.

RE-0724 and RE-0810 should be monitored once per 15 minutes until leakrate is stable (<10% change) for one hour; then monitoring can be reduced to once per 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .

When leakrate is stable for 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months monitoring can be reduced to once per shift.

PROCEDURE NO.

1

-REVISION NO.

20PAGE NO.

VEGP 18009-C WT20 A 22 of 24 B

OPERATION WITH A MINOR TUBE LEAK ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED B6.

IF Operations management has determined that the SG tube leakage does not warrant a unit shutdown, THEN repeat the steps of this section starting with Step BI.

B6.

IF Operations management has determined that a unit shutdown is warranted, THEN:

a.

Initiate a shutdown Mode 3 per 12004-C, POWER OPERATION (MODE 1).

to

b.

Continue with Step A4.

END OF SUB-PROCEDURE TEXT

PROCEDURE NO.

_REVISION NO.

PAGE NO.

VEGP 18009-C 20 23 of 24 Sheet 1 of 2 ATTACHMENT A DEFINITIONS AND ACTIONS CORRESPONDING TO PRIMARY TO SECONDARY LEAKRATES Normal Operation:

The plant condition in which no primary to secondary leakage is detected in routine surveillance (<5gpd).

No Operable Continuous Radiation Monitor (RE-0724 and RE-0810 inop):

This describes the condition where there is no continuous radiation monitor providing continuous automatic monitoring of primary-to secondary leakage.

Increased Monitoring:

This describes the condition in which leakage has been detected and quantified but is not in a range that can be accurately monitored by most radiation monitors (Ž5 gpd but <30 gpd).

Action:

Ensure radiation monitors RE-0724, RE-0810, RE-12839C, RE-0019, and RE-0021 are in service.

If any are not in service, ensure corrective action to return monitor(s) to service receives top priority (Frequency of monitoring per note prior to Step B3).

Action Level 1: Action Level 1 defines a plant condition in which leakage has increased to a condition that should be frequently monitored by the RMS with frequent benchmarking by laboratory analysis (Ž30 gpd but *75 gpd).

Actions:

Monitor primary to secondary leak rate by devoting an IPC terminal to the trending of RE-0724 and RE-0810 (preferred) and their rates of change and/or RE-12839C or RE-0019 or RE-0021 (Frequency of monitoring per note prior to Step B3.)

At each shift briefing review which procedures are to be utilized by operations, Chemistry, and HP in the event primary to secondary leakage worsens.

Action Level 2:

Action Level 2 defines a plant condition in which leakage has increased to a condition that suggests that the underlying flaw has grown to an undesirably large size and that the unit should be shut down in a controlled manner (Ž75 gpd for Ži hour and the rate of change is

<30 gpd/hr).

Action:

Unit shutdown is required.

Go to Step Al of this procedure and commence shutdown as directed by Step A3.

PROCEDURE NO.

NREVISION O.

ZVE GP 18009 -C 20 24 of 24 I PAGE NO.

Sheet 2 of 2 ATTACHMENT A (cont'd)

Action Level 3:

This action level describes a condition that suggests the leak is increasing rapidly and the unit should be promptly shut down (leak is significant and may get worse).

Action:

Unit shutdown is required.

Go to Step Al of this procedure and commence shutdown as directed by Step A3.

Large Tube Leak:

Describes a condition where the SG tube leakage is within the capability of one charging pump but is causing a noticeable mismatch between charging and letdown and rapid unit shutdown is warranted (Ž5 gpm).

Action:

A rapid unit shutdown is required.

Go to Step Al of this procedure and commence shutdown as directed by Step A3 using 18013-C "Rapid Power Reduction".

END OF ATTACHMENT A I

24 of 24 20

PROCEDURE NO.

REVISION NO.

PAGE NO.

VEGP 19111-C 24 4 of 36 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED NOTE:

5.

Determine containment spray requirements:

a.

Check spray pump suction -

FROM RWST.

HV-9017A -

CNMT SPRAY PMP-A RWST SUCT ISO VLV -

OPEN HV-9017B -

CNMT SPRAY PMP-B RWST SUCT ISO VLV -

OPEN

b.

Determine number of spray pumps required from Table:

a.

IF spray pump suction from sump, THEN go to Step 7.

c.

Check spray pumps running -

EQUAL TO NUMBER REQUIRED.

c.

Reset containment spray.

Operate spray pumps and discharge valves as required.

RWST CONTAINMENT FAN COOLERS SPRAY PUMPS LEVEL PRESSURE IN SLOW REQUIRED GREATER THAN GREATER 52 PSIG N/A 2

THAN 39%

BETWEEN 0

2 21.5 PSIG AND 4

1 52 PSIG 8

0 LESS THAN 21.5 PSIG N/A 0

GREATER THAN BETWEEN 52 PSIG N/A 2

10%

AND BETWEEN 21.5 39%

PSIG AND 52 3

1 PSIG 6

0 LESS THAN 21.5 PSIG N/A 0

LESS THAN 10%

N/A N/A 0

PROCEDURE NO.

REVISION NO.

PAGE NO.

VEGP 19111-C 24 5 of 36 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED NOTE:

Step 6 is not applicable to a LOCA outside containment.

6.

Check if containment spray should be aligned for recirculation:

a.

Check spray pumps RUNNING.

b.

Check containment emergency sump levels greater than or equal to 13.5 inches:

LI-764

-OR-

a.

Go to Step 7.

b.

WHEN containment emergency sump level indicators LI-764 or LI-765 greater than or equal to 13.5 inches, THEN perform Step 6c.

Continue with Step 7.

LI-765

c.

Initiate ATTACHMENT B, CONTAINMENT SPRAY SWITCHOVER FROM INJECTION TO RECIRCULATION.

7.

Makeup to RWST as necessary:

Initiate

13701, BORIC ACID SYSTEM.

-OR Initiate ATTACHMENT A, Makeup From Spent Fuel Pool.

VOGTLE ELECTRIC GENERATING PLANT (VEGP) UNIT 1 CYCLE 11 CORE OPERATING LIMITS REPORT REVISION 0 MARCH 2002

COLR for VEGP UNIT 1 CYCLE 11 1.0 CORE OPERATING LIMITS REPORT This Core Operating Limits Report (COLR) for VEGP UNIT 1 CYCLE 11 has been prepared in accordance with the requirements of Technical Specification 5.6.5.

The Technical Requirement affected by this report is listed below:

13.1.1 SHUTDOWN MARGIN - MODES 1 and 2 The Technical Specifications affected by this report are listed below:

3.1.1 SHUTDOWN MARGIN - MODES 3, 4 and 5 3.1.3 Moderator Temperature Coefficient 3.1.5 Shutdown Bank Insertion Limits 3.1.6 Control Bank Insertion Limits 3.2.1 Heat Flux Hot Channel Factor-F0(Z) 3.2.2 Nuclear Enthalpy Rise Hot Channel Factor - F,6NH 3.2.3 Axial Flux Difference 3.9.1 Boron Concentration PAGE 1 of 14

COLR for VEGP UNIT 1 CYCLE 11 2.0 OPERATING LIMITS The cycle-specific parameter limits for the specifications listed in section 1.0 are presented in the following subsections. These limits have been developed using NRC-approved methodologies, including those specified in Technical Specification 5.6.5.

2.1 SHUTDOWN MARGIN - MODES 1 AND 2 (Technical Requirement 13.1.1) 2.1.1 The SHUTDOWN MARGIN shall be greater than or equal to 1.30 percent Ak/k.

2.2 SHUTDOWN MARGIN - MODES 3 4 AND 5 (Specification 3.1.1) 2.2.1 The SHUTDOWN MARGIN shall be greater than or equal to the limits shown in Figures 1 and 2.

2.3 Moderator Temperature Coefficient (Specification 3.1.3) 2.3.1 The Moderator Temperature Coefficient (MTC) limits are:

The BOL/ARO/HZP - MTC shall be less positive than +0.7 x 104 Ak/k/JF for power levels up to 70 percent RTP with a linear ramp to 0 Ak/k/°F at 100 percent RTP.

The EOL/ARO/RTP-MTC shall be less negative than

-5.50 x 10i4 Alk/

1 F.'

2.3.2 The MTC Surveillance limits are:

The 300 ppm/ARO/RTP-MTC should be less negative than or equal to -4.75 x 104 Ak/k/WF.e The 60 ppm/ARO/RTP-MTC should be less negative than

-5.35 x 10' Ak/k/

1F.1 where:

BOL stands for Beginning of Cycle Life ARO stands for All Rods Out HZP stands for Hot Zero THERMAL POWER EOL stands for End of Cycle Life RTP stands for RATED THERMAL POWER 2.4 Shutdown Rank Insertion Limits (Specification 3.1.5) 2.4.1 The shutdown banks shall be withdrawn to a position greater than or equal to 225 steps.

2.5 Control Bank Insertion Limits (Specification 3.1.6) 2.5.1 The control banks shall be limited in physical insertion as shown in Figure 3.

"Applicable for full-power T-average of 586.40F to 587.40F.

PAGE 2 of 14

COLR for VEGP UNIT 1 CYCLE 11 2.6 Heat Flux Hot Channel Factor - Fo(Z) (Specification 3.2.1)

RTP Fa 2.6.1 FQ(Z)* _

K(Z)

P RTP Fa Fo(Z)

_* K(Z) 0.5 for P > 0.5 for P

0.5 where

P =

THERMAL POWER RATED THERMAL POWER RTP 2.6.2 Fe = 2.50 2.6.3 K(Z) is provided in Figure 4 RTP 2.6.4 FQ(Z) *< E!

o 2K(

P

W(Z)

RTP FQ(Z)

Fe

K(Z) 0.5

W(Z) for P > 0.5 for P_< 0.5 2.6.5 W(Z) values are provided in Figures 6 through 9.

2.6.6 The FQ(Z) penalty factors are provided in Table 1.

PAGE 3 of 14

COLR for VEGP UNIT 1 CYCLE 11 2.7 Nuilesar FnthAlpy Rise Hnt Channel Factnr - Fo H (Specification 3.2.2) 2.7.1 FH

FARlP

(1 + PFAH * (1-P))

where: P =

2.7.2 F'

THERMAL POWER RATED THERMAL POWER

= 1.65 2.7.3 PFAH = 0.3 2.8 Ax'il Flux Difference (Specification 3.2.3) 2.8.1 The Axial Flux Difference (AFD)

Figure 5.

acceptable operation limits are provided in 2.9 Boron Concentration (Specification 3.9.1) 2.9.1 The boron concentration shall be greater than or equal to 1970 ppm. 1 1This concentration bounds the condition of kf

0.95 (all rods in less the most reactive rod) and subcriticality (all rods out) over the entire cycle. This concentration includes additional boron to address uncertainties and B10 depletion.

PAGE 4 of 14

COLR for VEGP UNIT 1 CYCLE 11 TABLE 1 FQ(Z) PENALTY FACTOR Cycle Burnup (MWD/MTU) 30 150 363 576 789 1002 Fa(Z)

Penalty Factor 1.020 1.030 1.029 1.025 1.022 1.020 Notes:

1.

The Penalty Factor, to be applied to Fa(Z) in accordance with SR 3.2.1.2, is the maximum factor by which F0(Z) is expected to increase over a 39 EFPD interval (surveillance interval of 31 EFPD plus the maximum allowable extension not to exceed 25% of the surveillance interval per SR 3.0.2) starting from the burnup at which the Fa(Z) was determined.

2.

Linear interpolation is adequate for intermediate cycle burnups.

3.

For all cycle burnups outside the range of the table, a penalty factor of 1.020 shall be used.

PAGE 5 of 14

COLR for VEGP UNIT 1 CYCLE 11 5.00 3.00 00 oo UNACCEPTABLE OPERATING (950. 1.30)

REGION 00 An0.

500 1000 1500 2000 2500 217M11 RCS BORON CONCENTRATION (ppm)

FIGURE 1 REQUIRED SHUTDOWN MARGIN FOR MODES 3 AND 4 (MODE 4 WITH AT LEAST ONE REACTOR COOLANT PUMP RUNNING)

PAGE 6 of 14 d) z S z

0 Uo 2.

ACCEPTABLE OPERATING REGION (2500, 3.1j.o REQUIRED SHUTDOWN MARGIN 2

(1 0, 2.ooo 1.

A oooý

COLR for VEGP UNIT 1 CYCLE 11 ACCEPTABLE OPERATING REGION 5.00 4.00 g3.00 z

z R 2.00 0

0 1.00 (1250,

/

(460, 1.00) 1000 A

1500 7

UNACCEPTABLE OPERATING REGION 2000 RCS BORON CONCENTRATION (ppm)

FIGURE 2 REQUIRED SHUTDOWN MARGIN FOR MODES 4 AND 5 (MODE 4 WITH NO REACTOR COOLANT PUMPS RUNNING)

PAGE 7 of 14 REQUIRED SHUTDOWN MARGIN A

0.00&

0 500 2500 217MI 7

COLR for VEGP UNIT 1 CYCLE 11 2.0 4.0 6.0 8.0 10.0 CORE HEIGHT (ft)

FIGURE 4 K(Z) - NORMALIZED Fo(Z) AS A FUNCTION OF CORE HEIGHT PAGE 9 of 14 1.20 1.00 0

n-'

2F z

<C UJ]

0.

aJ I<j n

O:

0 z

0.80 0.60 0.40 0.20 Fo = 2.50 CORE HEIGHT g(Zl 0.000 1.000 6.000 1.000 12.000 0.925 0

0 12.0

COLR for VEGP UNIT 1 CYCLE 11 120 100 80 60 40 20

-50

-40

-30

-20

-10 0

10 20 30 40 50 AXIAL FLUX DIFFERENCE (percent Al)

FIGURE 5 AXIAL. FLUX DIFFERENCE LIMITS AS A FUNCTION OF % OF RATED THERMAL POWER FOR RAOC PAGE 10 of 14 J..

COLR for VEGP UNIT 1 CYCLE II N 1.

0.0 2.0 4.0 6.0 8.0 Core Height - feet This figure is referred to by Specfication Bu.2 Axial Point 1

2 3

4 5

6 7

8 9

10 11 12 13 14 15 16 17 18 19 20 21 22 23 A

24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 5D 51

52 10.0 12.0 53 55

. 56

57

58 Li 59 60 61

Top and Bottom 15% Excluded per Technical Specification B12.1 These W(Z) values are consistent with Figure 5 and are valid over the HFP Tavg temperature range from 586.40F to 587.40F.

FIGURE 6 RAOC W(Z) AT 150 MWD/MTU PAGE 11 of 14 Elevation fteo 11.60 11.40 11.20 11.00 10.80 10.60 10.40 10.20 10.00 9.80 9.60 9.40 9.20 9.00 8.80 8.60 8.40 8.20 8.00 7.80 7.60 7.40 7.20 7.00 6.80 6.60 6.40 6.20 6.00 5.80 5.60 5.40 5.20 5.00 4.80 4.60 4.40 4.20 4.00 3.80 MOO 3.60 3.40 3.20 3.00 2.8O 2.60 2.40 2.20 2.00 1.80 1.60 1.40 1.20 1.00 0.80 0.60 0.40 0.20 0.00 BOL 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.3488 1.3221 1.2927 1.2699 1.2496 1.2289 1.2186 1.2164 1.2196 1.2203 12243 1.2299 1.2317 1.2313 1.2286 1.2240 1.1935 1.1859 1.1784 1.1696 1.1592 1.1539 1.1546 1.1643 1.1783 1.1924 12053 12176 1.2290 1.2393 1.2484 1.2526 1.2570 1.2602 1.2609 1,2694 1.2865 13060 13252 1.3451 1.3659 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0001

COLR for VEGP UNIT I CYCLE 11 0.0 2.0 4.0 6.0 8.0 Core Height - feet This figure Is referred to by Spetfication B3.

1.

z0.0 2.0 Axial Point 1

2 3

4 5

6 7

8 9

10 11 12 13 14 15 16 17 18 S19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 59 60 61

Top and Botom 15% Exduded per Iecdical Specifiation B3.721 These W(Z) values are consistent with Figure 5 and are valid over the HFP Tao temperature range from 586.40F to 587.40F.

FIGURE 7 RAOC W(Z) AT 4000 MWDIMTU PAGE 12 of 14 Elevation MOLl1 11.80 1.0000 11.60 1.0000 11.40 1.0000 11.20 1.0000 11.00 1.0000 10.80 1.0000 10.60 1.0000 10.40 1.0000 1020 1.0000 10.00 13554 9.80 1.3231 9.60 12937 9.40 12756 9.20 12540 9.00 1.2404 8.80 1.2374 8.60 1.2374 8.40 12406 820 12412 8.00 1.2392 7.80 1.2351 7.60 1.2290 7.40 1.2211 720 12114 7.00 12001 6.80 1.1776 6.60 1.1680 6.40 1.1582 6.20 1.1499 6.00 1.1606 5.80 1.1548 5.60 1.1516 5.40 1.1560 5.20 1.1633 5.00 1.1702 4.80 1.1763 4.60 1.1816 4.40 1.1861 420 1.1896 4.00 1.1924 3.80 1.1987.

3.60 1.2063 3.40 12125 3.20 12202 3.00 1.2329 2.80 1.2525 2.60 12766 2.40 1.3002 2.20 13236 2.00 1.3469 1.80 1.0000 1.60 1.0000 1.40 1.0000 1.20 1.0000 1.00 1.0000 0.80 1.(000 0.60 1.0000 0.40 1b00" 0.20 1.0000 0.00 1.0000 1

1 1

1.

COLR for VEGP UNIT 1 CYCLE 11 1.i 1.!

1.

1.

1 1

1 0.0 2.0 4.0 6.0 8.0 Core Height - feet This figure is referred to by Spedlfcatlon D3 Axial Point 1

2 3

4 5

6 7

8 9

10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 10.0 12.0 53 54 55 56 57 58

.1 59 60 61 Elevation MOL-2 11.80 1.0000 11.60 1.0000 11.40 1.0000 11.20 1.0300 11.00 1.0000 10.80 1.0000 10.60 1.0000 10.40 1.0000 10.20 1.0000 10.00 1.3024 9.80 1.2899 9.60 1.2855 9.40 1.2785 9.20 1.2662 9.00 1.2544 8.80 1.2405 8.60 1.2309 8.40 1.2321 8.20 1.2315 8.00 1.2334 7.80 1.2390 7.60 1.2405 7.40 1.2397 7.20 1.2362 7.00 1.2305 6.80 1.2225 6.60 1.2127 6.40 1.2015 6.20 1.1898 6.00 1.1781 5.80 1.1699 5.60 1.1679 5.40 1.1710 5.20 1.1753 5.00 1.1785 4.80 1.1803 4.60 1.1808 4.40 1.1799 4.20 1.1778 4.00 1.1739 3.80 1.1707 3.60 1.1693 3.40 1.1673 3.20 1.1659 3.00 1.1659 2.80 1.1698 2.60 1.1775 2.40 1.1856 2.20 1.1937 2.00 1.2025 1.80 1.0000 1.60 1.0000 1.40 1.0000 1.20 1.0000 1.00 1.0000 0.80 1.0000 0.60 1.0000 0.40 1.0000 0.20 1.0000 0.00 1.0000

Top and Bottom 15% Excuded per Tedhical Spedfication B3.Z1 These W(Z) values are consistent with Figure 5 and are valid over the HFP Tayg temperature range from 586.40Fto 587.40F.

FIGURE 8 RAOC W(Z) AT 12000 MWD/MTU PAGE 13 of 14

COLR for VEGP UNIT 1 CYCLE 11 2.0 4.0 6.0 8.0 Core Height - feet Tbis figure is referred to by Spediication B3.

10.0 12.0 2.1

Thp and Bottm 15% Exclued per Technical Spedfication 832.1 These W(Z) values are consistent with Figure 5 and are valid over the HFP T.re temperature range from 586.40F to 587A4F.

FIGURE 9 RAOC W(Z) AT 20000 MWDIMTU PAGE 14 of 14 TK

~IZ I]L 11111II A

AA A

A A

AAA, Al I

A A

'AAAA

A A AA 4 AA 1.

1.5 N-.

1,2 1.01 0.0 Axial Point 1

2 3

4 5

6 7

8 9

10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 so 51 52 53 54 55 56 57 58 59 60 61 Elevation P2.9 11.80 11.60 11.40 11.20 11.00 10.80 10.60 "10.40 10.20 10.00 9.80 9.60 9.40 9.20 9.00 8.80 8.60 8.40 8.20 8.00 7.80 7.60 7.40 7.20 7.00 6.80 6.60 6.40 6.20 6.00 5.80 5.60 5.40 5.20 5.00 4.80 4.60 4.40 4.20 4.00 3,80 3.60 3.40 3.20 3.00 2.80 2.60 2.40 2.20 2.00 1.80 1.60 1.40 1.20 1.00 0.80 0.60 0.40 0.20 0.00 EOL 1.00]00 1.0000]

1.0000 1.005O 1.0000 1.0000 1.0000 1.0000 1.00(00 1.2251 1.2274 12273 1226 12255 1.27" 12507 1.2647 1.2749 12862 12946 1.2917 1.3028 1.3092 1.3121 1.3116 1-079 1.3012 1.2918 128OO 1.2653 1.2501 1.2416 1.2419 1.2441 1.2443 1.2424 1.2382 1.2318 1.2234 1.2120 1.2016 1.1940 1.1850 1.1746 1.1772 1.1760 1.1823 1.1875 1.1955 12045 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000

VOGTLE ELECTRIC GENERATING PLANT (VEGP) UNIT 2 CYCLE 10 CORE OPERATING LIMITS REPORT REVISION 0 OCTOBER 2002

COLR for VEGP UNIT 2 CYCLE 10 1.0 CORE OPERATING LIMITS REPORT This Core Operating Limits Report (COLR) for VEGP UNIT 2 CYCLE 10 has been prepared in accordance with the requirements of Technical Specification 5.6.5.

The Technical Requirement affected by this report is listed below:

13.1.1 SHUTDOWN MARGIN - MODES 1 and 2 The Technical Specifications affected by this report are listed below:

3.1.1 SHUTDOWN MARGIN - MODES 3,4 and 5 3.1.3 Moderator Temperature Coefficient 3.1.5 Shutdown Bank Insertion Limits 3.1.6 Control Bank Insertion Limits 3.2.1 Heat Flux Hot Channel Factor - FQ(Z) 3.2.2 Nuclear Enthalpy Rise Hot Channel Factor - FNH 3.2.3 Axial Flux Difference 3.9.1 Boron Concentration PAGE 1 of 14

COLR for VEGP UNIT 2 CYCLE 10 2.0 OPERATING LIMITS The cycle-specific parameter limits for the specifications listed in Section 1.0 are presented in the following subsections. These limits have been developed using NRC-approved methodologies, including those specified in Technical Specification 5.6.5.

2.1 SHUTDOWN MARGIN - MODES 1 AND 2 (Technical Requirement 13.1.1) 2.1.1 The SHUTDOWN MARGIN shall be greater than or equal to 1.30 percent Ak/k.

2.2 SHUTDOWN MARGIN - MODES 3, 4 AND 5 (Specification 3.1.1) 2.2.1 The SHUTDOWN MARGIN shall be greater than or equal to the limits shown in Figures 1 and 2.

2.3 Moderator Temperature Coefficient (Specification 3.1.3) 2.3.1 The Moderator Temperature Coefficient (MTC) limits are:

The BOL/ARO/HZP - MTC shall be less positive than +0.7 x 104 Ak/k/0F for power levels up to 70% RTP with a linear ramp to 0 Ak/k/PF at 100% RTP.

The EOL/ARO/RTP-MTC shall be less negative than -5.50 x 10.4 Ak/k/0F.1 2.3.2 The MTC Surveillance limits are:

The 300 ppm/ARO/RTP-MTC should be less negative than or equal to

-4.75 x 10.4 Ak/k/OF.l The 60 ppm/ARO/RTP-MTC should be less negative than

-5.35 x 10-4 Ak/k/OF. 1 where:

BOL stands for Beginning of Cycle Life ARO stands for All Rods Out HZP stands for Hot Zero THERMAL POWER EOL stands for End of Cycle Life RTP stands for RATED THERMAL POWER 2.4 Shutdown Bank Insertion Limits (Specification 3.1.5) 2.4.1 The shutdown banks shall be withdrawn to a position greater than or equal to 225 steps.

2.5 Control Bank Insertion Limits (Specification 3.1.6) 2.5.1 The control banks shall be limited in physical insertion as shown in Figure 3.

Applicable for full-power T-average of 586.40F to 587.40F.

PAGE 2 OF 14

COLR for VEGP UNIT 2 CYCLE 10 2.6 Heat Flux Hot Channel Factor - FQ(Z) (Specification 3.2.1)

RTP F0 2.6.1 FO(Z)

P

K(Z) for P > 0.5 RTP F0 FQ(Z)ý _<*K(Z) for P* 0.5

0.5 where

P =

THERMAL POWER RATED THERMAL POWER RTP 2.6.2 FQ = 2.50 2.6.3 K(Z) is provided in Figure 4.

RTP 2.6.4 FQ(Z)ý F._

K(Z)

P

W(Z) for P > 0.5 RTP F 0(Z)

fJ

-<2*K(Z) for P < 0.5 0.5

W(Z) 2.6.5 W(Z) values are provided in Figures 6 through 9.

2.6.6 The FQ(Z) penalty factors are provided in Table 1.

PAGE 3 of 14

COLR for VEGP UNIT 2 CYCLE 10 2.7 Nuclear Enthalpy Rise Hot Channel Factor-FkH (Specification 3.2.2) 2.7.1 FH

FARTP * (1 + PFAH * (1-P))

where: P 2.7.2 F P 2.7.3 PFAH THERMAL POWER RATED THERMAL POWER

=

1.65

=

0.3 2.8 Axial Flux Difference (Specification 3.2.3) 2.8.1 The Axial Flux Difference Figure 5.

(AFD) Acceptable Operation Limits are provided in 2.9 Boron Concentration (Specification 3.9.1) 2.9.1 The boron concentration shall be greater than or equal to 1810 ppm. 1 1This concentration bounds the condition of keff *0.95 (all rods in less the most reactive rod) and subcriticality (all rods out) over the entire cycle. This concentration includes additional boron to address uncertainties and B'0 depletion.

sAvogtle\\Colr\\COLR.U2 PAGE 4 of 14

COLR for VEGP UNIT 2 CYCLE 10 TABLE 1 Fo(Z) PENALTY FACTOR Cycle Burnup (MWD/MTU)

All Burnups F0(Z)

Penalty Factor 1.020 Notes:

1.

The Penalty Factor, to be applied to F0(Z) in accordance with SR 3.2.1.2, is the maximum factor by which F0(Z) is expected to increase over a 39 EFPD interval (surveillance interval of 31 EFPD plus the maximum allowable extension not to exceed 25% of the surveillance interval per SR 3.0.2) starting from the burnup at which the FQ(Z) was determined.

PAGE 5 of 14

COLR for VEGP UNIT 2 CYCLE 10 00 00 ACCEPTABLE OPERATING REGION (2500, 3.1_

00 (1600, 2.25) 00 UNACCEPTABLE OPERATING (950, 1.30)

REGION 00 nl 500 1000 1500 2000 2500 217&-1 RCS BORON CONCENTRATION (ppm)

FIGURE 1 REQUIRED SHUTDOWN MARGIN FOR MODES 3 AND 4 (MODE 4 WITH AT LEAST ONE REACTOR COOLANT PUMP RUNNING)

PAGE 6 of 14 5.

C) a.)

z a

z 0

0 I

cn Co a

w w

4.

3.

2.

1.

0.

0

COLR for VEGP UNIT 2 CYCLE 10 500 1000 1500 2000 ACS BORON CONCENTRATION (ppm)

FIGURE 2 REQUIRED SHUTDOWN MARGIN FOR MODES 4AND 5 (MODE 4 WITH NO REACTOR COOLANT PUMPS RUNNING)

PAGE 7 of 14 5.00 4.00 3.00 2.00 1.00 2 3z 5

z a,

Cc ACCEPTABLE OPERATING REGION UNACCEPTABLE OPERATING REGION (460, 1.00) 0 2500 2175&1 0.00

COLR for VEGP UNIT 2 CYCLE 10 2.0 9

I 4.0 6.0 8.0 10.0 CORE HEIGHT (ft)

FIGURE 4 K(Z) - NORMALIZED FO (Z) AS A FUNCTION OF CORE HEIGHT PAGE 9 of 14 n"

0 CU C.

N

..-i 0

z w N

fl cc 1.40 1.20 1.00 0.80 0.60 0.40 0.20 0

S S

I I

m

-umu Fa 2.50 CORE

-HEIGHT K(Z) 0.000 1.000 6.000 1.000

__ _12.000 0.925 0

12.0

COLR for VEGP UNIT 2 CYCLE 10

-40

-30

-20

-10 0

10 20 30 40 50 AXIAL FLUX DIFFERENCE (percent Al)

FIGURE 5 AXIAL FLUX DIFFERENCE LIMITS AS A FUNCTION OF,% OF RATED THERMAL POWER FOR RAOC PAGE 10 of 14 120 100 C,

I d) 4,"

a.

w 80 60 40

(-15, 100)

(+10,100)

UNACCEPTABLE UNACCEPTABLE ACCEPTABLE

(-30,50)

(+26, 50) 20 0'o-

COLR for VEGP UNIT 2 CYCLE 10 5-.-.

DZLJZDII Tall I Ik E16IT A

a A

Ahab 0.0 2.0 4.0 6.0 8.0 10.0 12.0 Core Height - feet This figure i referred to by Specification 13.2.1 These W(Z) values are consistent with Figure 5 and are valid over the HFP Ta.g temperature range from 586.4 to 587.4 0F.

6!

1.'

1..

Top and Bottom 15% Excluded per Technical Specification B3.2.1 FIGURE 6 RAOC W(Z) AT150 MWD/MTU PAGE 11 of 14 Axial Point 1

2 3

4 5

6 7

8 9

10 it 12

[3 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 S0 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 59 60 61 Elevation (feet) 12.00 11.80 11.60 11.40 11.20 11.00 10.80 10.60 10.40 10.20 10.00 9.80 9.60 9.40 9.20 9.00 8.80 8.60 8.40 8.20 8.00 7.80 7.60 7.40 7.20 7.00 6.80 6.60 6.40 6.20 6.00 5.80 5.60 5.40 5.20 5.00 4.80 4.60 4.40 4.20 4.00 3.80 3.60 3.40 3.20 3.00 2.80 2,60 2.40 2.20 2.00 1.80 1.60 1.40 1.20 1.00 0.80 0,60 0.40 0.20 0.00 1.4 1.3 1.2 1.1 BOL W(z) 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1,0000 1.3331 1.2984 1.2789 1.2734 1.2625 1.2592 1.2636 1.2723 1.2770 1.2800 1.2794 1.2802 1.2801 1.2762 1.2697 1.2609 1.2252 1.2127 1.1985 1.1828 1.1708 1.1662 1.1635 1.1638 1.1692 1.1783 1.1875 1,1957 1:2029 1.2090 1.2173 1.2231 1.2281 1,2316 1.2337 1.2390 1.2492 1.2612 1.272V 1.2881 1.3053 1.0000 1.0000 1.0000 I.0000 1.0000 1.0000 1.0000 1.0000 1.0O00 1.0000 1

COLR for VEGP UNIT 2 CYCLE 10 I

I C

I 0.0 2.0 4.0 6.0 8.0 10.0 Core Height - feet This figure is referred to by Specification B3.2.1 These W(Z) values are consistent with Figure 5 and are valid over the 11FF Ta,, temperature range from 586.4 to 587.4 0F.

12.

12.0

1.

Axial Point 2

3 4

5

6 7

8 10 11 12 13 14 15 16 17 is 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 59 60 i61 Elevation (feet) 12.00 11.80 11.60 11.40 11.20 11.00 10.80 10.60 10.40 10.20 10.00 9.80

.9.60 9.40 9.20 9.00 8.80 8.60 8.40 8.20 8 00 780 7 60 7.40 7.20 7.00 6.80 6.60 6.40 6.20 6.00 5.80 5.60 5.40 5.20 5.00 4.80 4.60 4.40 4.20 4.00 3.80 3.60 3.40 3.20 3.00 2.80 2.60 2.40 2.20 2.00 1.80 1.60 1.40 1.20 1.00 0.80 0.60 0.40 0.20 000 "Top and Bottom 15% Excluded per Technical Specification 83.2.1 FIGURE 7 RAOC W(Z) at 4000 MWD/MTU PAGE 12 of 14 MOL-I WMZ 1,0000 1.0000 1.0000 1 0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.0000 1.3967 1.3673 1.3446 1.3272 1.3026 1,2783 1.2633 1.2582 1.2560 1,2516 1.2518 1 2508 1.2464 1.2397 1.2309 1.2203 1.1958 1.1824 1.1701 1.1617 3.1700 1.1626 1.1566 1.1528 1.1573 1.1634 M,.685 1.1731 1.1773 1.1819 1,1863 1.1922 1.1967 1.2005 1.2056 1.2126 1.2250 1.2424 1.2600 1.2790 1.3003 1.0000 1.0000 1.0000 1.0000 1.0000 1,0000 1.0000 1.0000 1.0000 1.0000

1.

N 1,:

1.1 1.

COLR for VEGP UNIT 2 CYCLE 10

]II I 1 1I Eli IT-ilIIF I I917I21La~ aTT

'A A

A A

AAA&

1 2.0 4.0 6.0 8.0 Core Height - feet 10.0 12.

This figure Is referred to by Speeification B3.2.1 These W(Z) values are consistent with Figure 5 and are valid over the HFP Tavg temperature range from 586.4 to 587.4 0F.

11 1.!

FIGURE 8 RAOC W(Z) AT 12000 MWD/MTU PAGE 13 of 14 P

"1.3 1.2 1.1 1.0 0,0 Axial Elevation MOL-2 Point (feet)

W(Z) 1 12.00 1.0000 2

11.80 1.0000 3

11.60 1.0000 4

11.40 1.0000 5

11.20 1.0000 6

11.00 1.0000 7

10.80 1.0000 8

10.60 1.0000 9

10.40 1.0000 10 10.20 1.0000 11 10.00 1.2757 12 9.80 1.2740 13 9.60 1.2701 14 9.40 1.2635 15 9.20 1.2563 16 9.00 1.2442 17 8.80 1.2380 18 8.60 1.2368 19 8.40 1.2404 20 8.20 1.2415 21 8.00 1.2457 22 7.80 1.2515 23 7.60 1.2535 24 7.40 1.2529 25 7.20 1.2495 26 7.00 1.2437 27 6.80 1.2356 28 6.60 1.2254 29 6.40 1.2140 30 6.20 1.2024 31 6.00 1.1887 32 5.80 1.1762 33 5.60 1.1718 34 5.40 1.1771 35 5,20 1.1833 36 5.00 1.1886 37 4.80 1.1926 38 4.60 1.1952 39 4.40 1.1964 40 4.20 1.1961 41 4.00 1.1944 42 3.80 1.1911 43 3.60 1.1871 44 3.40 1.1836 45 3.20 1.1821 46 3.00 1.1834 47 2.80 1.1897 48 2.60 1.1991 49 2.40 1.2087 50 2.20 1.2182 51 2.00 1.2276 52 1.80 1.0000 53 1.60 1.0000

.0 54 1.40 1.0000 55 1.20 1.0000 56 1.00 1.0000 57 0.80 1.0000 58 0.60 1.0000 59 0.40 1.0000 6 80 0.20 1.0000 61 0.00 1.0000

Top and Bottom 15% Excluded per Technical Specification B3.2.1 0

COLR for VEGP UNIT 2 CYCLE 10 5 --

-I IA 1.'j ii N

I.'

1.)

A A a

A0 -

AAA&

-liii ILIJILI 2.0 I I I I II II F 10.0 12 4.0 6.0 8.0 Core Height - feet This figure is referred to by Specification B3.2.1 These W(Z) values are consistent with Figure 5 and are valid over the HFP Tavg temperature range from 586.4 to 587.4°F.

6 FIGURE 9 RAOC W(Z) AT 20000 MWD/MTU PAGE 14 of 14 II AA 16 I.01L 0.0 Axial Elevation EOL Point (feet)

W(Z)

I 12.00 1.0000 2

11.80 1.0000 3

11.60 1.0000 4

11.40 1.0000 5

11.20 1.0000 6

11.00 1.0000 7

10.80 1.0000 8

10.60 1.0000 9

10.40 1.0000 10 10.20 1.0000 II 10.00 1.2297 12 9.80 1.2271 13 9.60 1.2312 14 9.40 1.2309 15 9.20 1.2297 16 9.00 1.2348 17 8.80 1.2400 18 8.60 1.2451 19 8.40 1.2556 20 8.20 1.2726 21 8.00 1.2865 22 7.80 1.2853 23 7.60 1.2940 24 7.40 1.2995 25 7.20 1.3020 26 7.00 1.3017 27 6.80 1.2982 28 6.60 1.2936 29 6.40 1.2893 30 6.20 1.2834 31 6.00 1.2758 32 5.80 1.2660 33 5.60 1.2573 34 5.40 1.2539 35 5.20 1.2543 36 5.00 1.2532 37 4.80 1.2514 38 4.60 1.2487 39 4.40 1.2434 40 4.20 1.2358 41 4.00 1.2260 42 3.80 1.2141 43 3.60 1.2008 44 3.40 1.1880 45 3.20 1.1776 46 3.00 1.1848 47 2.80 1.1865 48 2.60 1.1977 49 2.40 1.2078 50 2.20 1.2179 51 2.00 1.2281 52 1.80 1.0000 53 1.60 1.0000

.0 54 1.40 1.0000 55 1.20 1.0000 56 1.00 1.0000 57 0.80 1.0000 58 0.60 1.0000 59 0.40 1.0000 60 0.20 1.0000 61 0.00 1.0000

Top and Bottom 15% Excluded per Technical Specification B3.2.1

-2 2

Vogtle 2002-301 l]frOZ*frd SRO Inital Exam

69. Given the following plant conditions:

- Unit is at 100%

- RCS Dose Equivalent Iodine-131 sample taken 0730 on 11/04/02 is 6.30 xCi/gram.

- RCS Dose Equivalent Iodine-131 sample taken 0730 on 11/06/02 is now 2.5.$Ci/gram.

Based on these conditions which ONE of the following is the required action(s)?

A. Place all CVCS demins in service at maximum flow rate and continue power operations.

B. Place the Unit in Mode 3 at less than 500 degrees F within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

C. Continue to monitor dose equivalent Iodine 131 to ensure it remains within acceptable region once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

D. Complete a load reduction to less than 50% within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and monitor RCS Dose Equivalent lodine-131 every 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

Vogtle 2002-301 SRO Inital Exam S11/26/02

'-*tt*

"4 0 *f A1 A C"

56. The crew is in 19100-C, "

"o'.

Prior to the step that the crew places equipment in PTL, the procedure cautions that 2 NSCW pumps should be available to load on each AC Emergency Bus.

These pumps are required to provide cooling for the.........

A. SI pump B. MDAFW pump C. ACCW pump D. EDG

Vogtle 2002-301 RO Inital Exam 11/26/02

62. The crew is in 19100-C, ".ctzr Trip or fet..... ot.en'. Prior to the step that the crew places equipment in PTL, the procedure cautions that 2 NSCW pumps should be available to load on each AC Emergency Bus.

These pumps are required to provide cooling for the.........

A. SI pump B. MDAFW pump C. ACCW pump D. EDG

ML030560850

Text

0.5 where

0.5 where

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