Text

Technical Specifications for License Amendment Nos. 158 and 149, Pages 3.4.13-1 to 5.0-4.5 (215 Pages)
	ML022210054
Person / Time
Site:	Prairie Island
Issue date:	07/26/2002
From:	; NRC/NRR/DLPM
To:	;
References
	TAC MB0695, TAC MB0696
	Download: ML022210054 (215)
	v • d • e

LTOP - RCSCLT _<SI Pump Disable Temperature 3.4.13 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.13 Low Temperature Overpressure Protection (LTOP) - Reactor Coolant System Cold Leg Temperature (RCSCLT) _<Safety Injection (SI) Pump Disable Temperature LCO 3.4.13 LTOP shall be provided with: 1) no SI Pumps capable of injecting into the RCS; 2) the emergency core cooling system (ECCS) accumulators isolated; and 3) one of the following pressure relief capabilities:

a. An Over Pressure Protection System (OPPS) shall be OPERABLE with two pressurizer power operated relief valves (PORVs) with lift settings within the limits specified in the PTLR; or

b. The RCS depressurized and an RCS vent of > 3 square inches.

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

1. Both safety injection (SI) pumps may be run for _<1 hour while conducting SI system testing provided there is a steam or gas bubble in the pressurizer, the reactor vessel head is on, and at least one isolation valve between the SI pump and the RCS is shut.

2. During reduced inventory conditions an SI pump may be run as required to maintain adequate core cooling and RCS inventory.

3. ECCS accumulator may be unisolated when ECCS accumulator pressure is less than the maximum RCS pressure for the existing RCS cold leg temperature allowed by the P/T limit curves provided in the PTLR.

APPLICABILITY: MODE 4 when any RCS cold leg temperature is _<the SI Pump disable temperature specified in the PTLR, MODE 5 when the steam generator (SG) primary system manway and pressurizer manway are closed and secured in position, MODE 6 when the reactor vessel head is on and the SG primary system manway and pressurizer manways are closed and secured in position.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.4.13-1 Unit 2 - Amendment No. 149

LTOP - RCSCLT < SI Pump Disable Temperature 3.4.13 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or both SI pump(s) A. 1 Initiate action to verify no SI Immediately capable of injecting into pump is capable of injecting the RCS. into the RCS.

B. An ECCS accumulator B.1 Isolate affected ECCS 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months not isolated when the accumulator.

ECCS 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 hours0.5 days 0.0714 weeks 0.0164 months associated Completion temperature to > the OPPS Time of Condition B not enable temperature specified met. in the PTLR.

OR C.2 Depressurize affected ECCS 12 hours0.5 days 0.0714 weeks 0.0164 months accumulator to less than the maximum RCS pressure for existing cold leg temperature allowed in the PTLR.

Prairie Island Unit 1 - Amendment No. 158 Units I and 2 3.4.13-2 Unit 2 - Amendment No. 149

LTOP - RCSCLT :<SI Pump Disable Temperature 3.4.13 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. ------- NOTE --------- D. I Restore required PORV to 24 hours1 days 0.143 weeks 0.0329 months Only applicable in LCO OPERABLE status.

3.4.13.a.

One required PORV inoperable.

E. Two required PORVs E. 1 Depressurize RCS and 8 hours0.333 days 0.0476 weeks 0.011 months inoperable for LCO establish RCS vent of > 3 3.4.13.a. square inches.

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

OR OPPS inoperable.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.4.13-3 Unit 2 - Amendment No. 149

LTOP - RCSCLT !<SI Pump Disable Temperature 3.4.13 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.13.1 Verify no SI pumps are capable of injecting into 12 hours0.5 days 0.0714 weeks 0.0164 months the RCS.

SR 3.4.13.2 Verify each ECCS accumulator is isolated. Once within 12 hours0.5 days 0.0714 weeks 0.0164 months and every 12 hours0.5 days 0.0714 weeks 0.0164 months thereafter SR 3.4.13.3 ------------------- NOTE ----------------

Only required to be performed when complying with LCO 3.4.13.b.

Verify required RCS vent > 3 square inches open. 12 hours0.5 days 0.0714 weeks 0.0164 months for unlocked open vent valve(s)

AND 31 days for other vent path(s)

SR 3.4.13.4 Verify PORV block valve is open for each 72 hours3 days 0.429 weeks 0.0986 months required PORV.

Prairie Island Unit I - Amendment No. 158 Units I and 2 3.4.13-4 Unit 2 - Amendment No. 149

LTOP - RCSCLT :< SI Pump Disable Temperature 3.4.13 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.13.5 --------------------------- NOTE-- ----------

Not required to be performed until 12 hours0.5 days 0.0714 weeks 0.0164 months after decreasing RCS cold leg temperature to *< the OPPS enable temperature specified in the PTLR.

Perform a COT on OPPS. 31 days SR 3.4.13.6 Perform CHANNEL CALIBRATION for OPPS 24 months actuation channel.

Prairie Island Unit I - Amendment No. 158 Units 1 and 2 3.4.13-5 Unit 2 - Amendment No. 149

RCS Operational LEAKAGE 3.4.14 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.14 RCS Operational LEAKAGE LCO 3.4.14 RCS operational LEAKAGE shall be limited to:

a. No pressure boundary LEAKAGE;

b. I gpm unidentified LEAKAGE;

c. 10 gpm identified LEAKAGE; and

d. 150 gallons per day primary to secondary LEAKAGE through any one steam generator (SG).

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RCS unidentified A. 1 Reduce LEAKAGE to 4 hours0.167 days 0.0238 weeks 0.00548 months LEAKAGE not within within limits.

limit.

B. Required Action and B.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time of Condition A not AND met.

B.2.1 Identify LEAKAGE. 54 hours2.25 days 0.321 weeks 0.074 months OR B.2.2 Be in MODE 5. 84 hours3.5 days 0.5 weeks 0.115 months Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.4.14-1 Unit 2 - Amendment No. 149

RCS Operational LEAKAGE 3.4.14 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. RCS identified C.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months LEAKAGE not within limit for reasons other AND than pressure boundary LEAKAGE. C.2.1 Reduce LEAKAGE to 14 hours0.583 days 0.0833 weeks 0.0192 months within limits.

OR C.2.2 Be in MODE 5. 44 hours1.833 days 0.262 weeks 0.0603 months D. Pressure boundary D. 1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months LEAKAGE exists.

AND OR D.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months SG LEAKAGE not within limit.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.4.14-2 Unit 2 - Amendment No. 149

RCS Operational LEAKAGE 3.4.14 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.14.1 -------------------- NOTE ---------------

Not required to be performed until 12 hours0.5 days 0.0714 weeks 0.0164 months after establishment of steady state operation.

Verify RCS operational leakage within limits by 24 hours1 days 0.143 weeks 0.0329 months performance of RCS water inventory balance.

SR 3.4.14.2 Verify steam generator tube integrity is in In accordance accordance with the Steam Generator Program. with the Steam Generator Program Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.4.14-3 Unit 2 - Amendment No. 149

RCS PIV Leakage 3.4.15 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.15 RCS Pressure Isolation Valve (PIV) Leakage LCO 3.4.15 Leakage from each RCS PIV shall be within limit.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS

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

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.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.4.15-1 Unit 2 - Amendment No. 149

RCS PIV Leakage 3.4.15 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more flow paths ------------- NOTE ---------

with leakage from one or Each valve used to satisfy more RCS PIVs not Required Action A. l must have within limit, been verified to meet SR 3.4.15.1 and be in the high pressure portion of the system.

A.1 Isolate the high pressure 4 hours0.167 days 0.0238 weeks 0.00548 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 Restore RCS PIV to within 72 hours3 days 0.429 weeks 0.0986 months limits.

B. Required Action and B.I Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months Prairie Island Unit 1 - Amendment No. 158 Units I and 2 3.4.15-2 Unit 2 - Amendment No. 149

RCS PIV Leakage 3.4.15 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.15.1 --------------- NOTE ----------------

Not required to be performed in MODES 3 and 4.

Verify leakage from each RCS PIV is equivalent to In accordance

_* 0.5 gpm per nominal inch of valve size up to a with the maximum of 5 gpm at an RCS pressure >!2215 psig Inservice Testing and _<2255 psig. Program, and 24 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 I ____________________________

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.4.15-3 Unit 2 - Amendment No. 149

RCS Leakage Detection Instrumentation 3.4.16 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.16 RCS Leakage Detection Instrumentation LCO 3.4.16 The following RCS leakage detection instrumentation shall be OPERABLE:

a. One containment sump A monitor (pump run time instrumentation);

and

b. One containment radionuclide monitor.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS

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

LCO 3.0.4 is not applicable.

CONuITION REQUIRED ACTION COMPLETION TIME A. Required containment A. 1---------NOTE------

sump monitor inoperable. Not required until 12 hours0.5 days 0.0714 weeks 0.0164 months after establishment of steady state operation.

Perform SR 3.4.14.1. Once per 24 hours1 days 0.143 weeks 0.0329 months AND Prairie Island Unit I - Amendment No. 158 Units 1 and 2 3.4.16-1 Unit 2 - Amendment No. 149

RCS Leakage Detection Instrumentation 3.4.16 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2 Restore required 30 days containment sump monitor to OPERABLE status.

B. Required containment B.1.1 Analyze grab samples of Once per 24 hours1 days 0.143 weeks 0.0329 months radionuclide monitor the containment inoperable, atmosphere.

OR B.1.2 --------- NOTE------

Not required until 12 hours0.5 days 0.0714 weeks 0.0164 months after establishment of steady state operation.

Perform SR 3.4.14. 1. Once per 24 hours1 days 0.143 weeks 0.0329 months AND B.2 Restore required 30 days containment radionuclide monitor to OPERABLE status.

C. Required Action and C.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND C.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.4.16-2 Unit 2 - Amendment No. 149

RCS Leakage Detection Instrumentation 3.4.16 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. All required monitors D.1 Enter LCO 3.0.3. Immediately inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.16.1 Perform CHANNEL CHECK of the required 12 hours0.5 days 0.0714 weeks 0.0164 months containment radionuclide monitor.

SR 3.4.16.2 Perform COT of the required containment 92 days radionuclide monitor.

SR 3.4.16.3 Perform CHANNEL CALIBRATION of the 24 months required containment sump monitor.

SR 3.4.16.4 Perform CHANNEL CALIBRATION of the 24 months required containment radionuclide monitor.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.4.16-3 Unit 2 - Amendment No. 149

RCS Specific Activity 3.4.17 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.17 RCS Specific Activity LCO 3.4.17 The specific activity of the reactor coolant shall be within limits.

APPLICABILITY: MODES 1 and 2, MODE 3 with RCS average temperature (Tavg) ->500'F.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. DOSE EQUIVALENT ------------- Note---------

1-131 > 1.0jjCi/gm. LCO 3.0.4 is not applicable.

A. 1 Verify DOSE Once per 4 hours0.167 days 0.0238 weeks 0.00548 months EQUIVALENT I-131 within the acceptable region of Figure 3.4.17-1.

AND A.2 Restore DOSE 48 hours2 days 0.286 weeks 0.0658 months EQUIVALENT 1-131 to within limit.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.4.17-1 Unit 2 - Amendment No. 149

RCS Specific Activity 3.4.17 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Gross specific activity B.1 Be in MODE 3 with 6 hours0.25 days 0.0357 weeks 0.00822 months of the reactor coolant Tavg < 500F.

not within limit.

C. Required Action and C. 1 Be in MODE 3 with 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Tavg < 500 0 F.

Time of Condition A not met.

OR DOSE EQUIVALENT 1-131 in the unacceptable region of Figure 3.4.17-1.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.17.1 Verify reactor coolant gross specific activity 7 days

< 100/2 uCi/gm.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.4.17-2 Unit 2 - Amendment No. 149

RCS Specific Activity 3.4.17 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY I

SR 3.4.17.2 NOTE --------------

Only required to be performed in MODE 1.

Verify reactor coolant DOSE EQUIVALENT 14 days 1-131 specific activity _<1.0 /.Ci/gm.

AND Between 2 and 6 hours0.25 days 0.0357 weeks 0.00822 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 SR 3.4.17.3 --------------

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

Not required to be performed until 31 days after a minimum of 2 effective full power days and 20 days of MODE I operation have elapsed since the reactor was last subcritical for Ž 48 hours2 days 0.286 weeks 0.0658 months .

Determine 2 from a sample taken in MODE 1 after 184 days 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 hours2 days 0.286 weeks 0.0658 months .

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.4.17-3 Unit 2 - Amendment No. 149

RCS Specific Activity 3.4.17 250

' - t NJ I

+T__7-z 0 200 ILI 0

=L I I!

-~41 L

U 150 UNACCEPTABLE

ý, t_ OPERATION z 1ý6 0-4 U

U a* w 100 C 1 1 ; 1 1 A__

50

-T)

ACCEPTABLE OPERATION 0

20 30 40 50 60 70 80 90 100 PERCENT OF RATED THERMAL POWER Figure 3.4.17-1 (page 1 ofl)

Reactor Coolant DOSE EQUIVALENT 1-131 Specific Activity Limit Versus Percent of RATED THERMAL POWER Prairie Island Unit 1 - Amendment No. 158 Units I and 2 3.4.17-4 Unit 2 - Amendment No. 149

RCS Loops - Test Exceptions 3.4.18 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.18 RCS Loops -Test Exceptions LCO 3.4.18 The requirements of LCO 3.4.4, "RCS Loops- MODES I and 2," may be suspended, with THERMAL POWER < P-7.

APPLICABILITY: MODES 1 and 2 during startup and PHYSICS TESTS.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. THERMAL POWER A. 1 Open reactor trip breakers. Immediately

> P-7.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.18.1 Verify THERMAL POWER is < P-7. 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months SR 3.4.18.2 Perform a COT for each power range neutron Prior to initiation flux - low and intermediate range neutron flux of startup and channel and P-7. PHYSICS TESTS Prairie Island Unit 1 - Amendment No. 158 Units I and 2 3.4.18-1 Unit 2 - Amendment No. 149

Accumulators 3.5.1 3.5 EMERGENCY CORE COOLING SYlSTEZMS (ECCS) 3.5.1 Accumulators LCO 3.5.1 Two ECCS accumulators shall be OPERABLE.

APPLICABILITY: MODES I and 2, MODE 3 with RCS pressure> 1000 psig.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One accumulator A. 1 Restore boron 72 hours3 days 0.429 weeks 0.0986 months inoperable due to boron concentration to within concentration not within limits.

limits.

B. One accumulator B.1 Restore accumulator to 24 hours1 days 0.143 weeks 0.0329 months inoperable for reasons OPERABLE status.

other than Condition A.

C. Required Action and C.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time of Condition A AND or B not met.

C.2 Reduce RCS pressure to 12 hours0.5 days 0.0714 weeks 0.0164 months

< 1000 psig.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.5.1-1 Unit 2 - Amendment No. 149

Accumulators 3.5.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Two accumulators D.1 Enter LCO 3.0.3. Immediately inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.1 Verify each accumulator isolation valve is fully 12 hours0.5 days 0.0714 weeks 0.0164 months open.

SR 3.5.1.2 Verify borated water volume in each accumulator 12 hours0.5 days 0.0714 weeks 0.0164 months is > 1250 cubic feet (25%) and < 1290 cubic feet (91%).

SR 3.5.1.3 Verify nitrogen cover pressure in each 12 hours0.5 days 0.0714 weeks 0.0164 months accumulator is > 710 psig and < 770 psig.

SR 3.5.1.4 Verify boron concentration in each accumulator is 31 days

> 1900 ppm.

SR 3.5.1.5 Verify power is removed from each accumulator 31 days isolation valve operator when RCS pressure is

> 2000 psig.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.5.1-2 Unit 2 - Amendment No. 149

ECCS - Operating 3.5.2 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.2 ECCS - Operating LCO 3.5.2 Two ECCS trains shall be OPERABLE.

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

In MODE 3, both safety injection (SI) pump flow paths may be isolated by closing the isolation valves for up to 2 hours0.0833 days 0.0119 weeks 0.00274 months to perform pressure isolation valve testing per SR 3.4.15.1.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more trains A. 1 Restore train(s) to 72 hours3 days 0.429 weeks 0.0986 months inoperable. OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND B.2 Be in MODE 4. 12 hours0.5 days 0.0714 weeks 0.0164 months C. Less than 100% of the C.1 Enter LCO 3.0.3. Immediately ECCS flow equivalent to a single OPERABLE ECCS train available.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.5.2-1 Unit 2 - Amendment No. 149

ECCS - Operating 3.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE EQUIREMENTS SURVEILLANCE FREQUENCY 1-SR 3.5.2.1 Verify the following valves are in the listed position. 12 hours0.5 days 0.0714 weeks 0.0164 months Westing Unit 1 house Valve Valve Number Number Position Function 32070 8801A OPEN SI Injection to RCS Cold Leg A 32068 8801B OPEN SI Injection to RCS Cold Leg B 32073 8806A OPEN SI Cold Leg Injection Line 32206 8816A CLOSED SI Pump Suction from RHR 32207 8816B CLOSED SI Pump Suction from RHR Westing Unit 2 house Valve Valve Number Number Position Function 32173 8801A OPEN SI Injection to RCS Cold Leg A 32171 8801 B OPEN SI Injection to RCS Cold Leg B 32176 8806A OPEN SI Cold Leg Injection Line 32208 8816A CLOSED SI Pump Suction from RHR 32209 8816B CLOSED SI Pump Suction from RHR SR 3.5.2.2 Verify each ECCS manual, power operated, and 31 days automatic valve in the flow path that is not locked, sealed, or otherwise secured in position, is in the correct position.

SR 3.5.2.3 Verify power to the valve operator has been removed 31 days for each valve listed in SR 3.5.2.1.

Prairie Island Unit I - Amendment No. 158 Units 1 and 2 3.5.2-2 Unit 2 - Amendment No. 149

ECCS - Operating 3.5.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.2.4 Verify each ECCS pump's developed head at the test In accordance flow point is greater than or equal to the required with the developed head. Inservice Testing Program SR 3.5.2.5 Verify each ECCS automatic valve in the flow path 24 months that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.

SR 3.5.2.6 Verify each ECCS pump starts automatically on an 24 months actual or simulated actuation signal.

SR 3.5.2.7 Verify each ECCS throttle valve listed below is in 24 months the correct position.

Unit I Valve Number Unit 2 Valve Number SI-15-6 2SI-15-6 SI-15-7 2SI-15-7 SI-15-8 2SI-15-8 SI-15-9 2SI-15-9 SR 3.5.2.8 Verify, by visual inspection, each ECCS train 24 months containment sump suction inlet is not restricted by debris and the suction inlet trash racks and screens show no evidence of structural distress or abnormal corrosion.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.5.2-3 Unit 2 - Amendment No. 149

ECCS - Shutdown 3.5.3 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.3 ECCS - Shutdown LCO 3.5.3 One ECCS train shall be OPERABLE.

N OTE An RHR train may be considered OPERABLE during alignment and operation for decay heat removal, if capable of being manually realigned to the ECCS mode of operation.

APPLICABIITY: MODE 4 when both RCS cold leg temperatures are > SI pump disable temperature specified in PTLR.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Required ECCS residual A. 1 Initiate action to restore Immediately heat removal (RHR) required ECCS RHR subsystem inoperable, subsystem to OPERABLE status.

B. Required ECCS safety B. 1 Restore required ECCS SI 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months injection (SI) subsystem subsystem to OPERABLE inoperable, status.

C. Required Action and C.1 Be in MODE 5. 24 hours1 days 0.143 weeks 0.0329 months associated Completion Time of Condition B not met.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.5.3-1 Unit 2 - Amendment No. 149

ECCS - Shutdown 3.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.3.1 The following SRs are applicable for all equipment In accordance required to be OPERABLE: with applicable SRs SR 3.5.2.1 SR 3.5.2.7 SR 3.5.2.3 SR 3.5.2.8 SR 3.5.2.4 Prairie Island Unit 1 -Amendment No. 158 Units 1 and 2 3.5.3-2 Unit 2 - Amendment No. 149

RWST 3.5.4 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.4 Refueling Water Storage Tank (RWST)

LCO 3.5.4 The RWST shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RWST boron A. 1 Restore RWST to 8 hours0.333 days 0.0476 weeks 0.011 months concentration not within OPERABLE status.

limits.

B. RWST borated water B. 1 Restore RWST to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months volume not within limits. OPERABLE status.

C. Required Action and C.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND C.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months Prairie Island Unit 1 - Amendment No. 158 Units I and 2 3.5.4-1 Unit 2 - Amendment No. 149

RWST 3.5.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.4.1 Verify RWST borated water volume is >_ 200,000 7 days gallons (68%).

SR 3.5.4.2 Verify RWST boron concentration is >_ 2600 ppm 7 days and !<3500 ppm.

Prairie Island Unit 1 - Amendment No. 158 3.5.4-2 Unit 2 - Amendment No. 149 Units I and 2

Containment 3.6.1 3.6 CONTAINMENT SYSTEMS 3.6.1 Containment LCO 3.6.1 Containment shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Containment inoperable. A.1 Restore containment to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months I I Prairie Island Unit 1 - Amendment No. 158 Units I and 2 3.6.1-1 Unit 2 - Amendment No. 149

Containment 3.6.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.1 Perform required visual examinations and leakage In accordance rate testing except for containment air lock testing, in with the accordance with the Containment Leakage Rate Containment Testing Program. Leakage Rate Testing Program SR 3.6.1.2 Verify containment average air temperature :< 44'F Prior to entering above shield building average air temperature. MODE 4 from MODE 5 SR 3.6.1.3 Verify containment shell temperature Ž>30TF. Prior to entering MODE 4 from MODE 5 Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.6.1-2 Unit 2 - Amendment No. 149

Containment Air Locks 3.6.2 3.6 CONTAINMENT SYSTEMS 3.6.2 Containment Air Locks LCO 3.6.2 Two containment air locks shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS

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

1. Entry and exit is permissible to perform repairs on the affected air lock components.

2. Separate Condition entry is allowed for each air lock.

3. Enter applicable Conditions and Required Actions of LCO 3.6.1, "Containment,"

when air lock leakage results in exceeding the overall containment leakage rate acceptance criteria.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.6.2-1 Unit 2 - Amendment No. 149

Containment Air Locks 3.6.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more NOTES--------

containment air locks 1. Required Actions A. 1, A.2, with one containment air and A.3 are not applicable lock door inoperable, if both doors in the same air lock are inoperable and Condition C is entered.

2. Entry and exit is permissible for 7 days under administrative controls if both air locks are inoperable.

A.l Verify the OPERABLE 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months door is closed in the affected air lock.

AND A.2 Lock the OPERABLE door 24 hours1 days 0.143 weeks 0.0329 months closed in the affected air lock.

AND Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.6.2-2 Unit 2 - Amendment No. 149

Containment Air Locks 3.6.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.3 --------- NOTE-------

Air lock doors in high radiation areas may be verified locked closed by administrative means.

Verify the OPERABLE Once per 31 days door is locked closed in the affected air lock.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.6.2-3 Unit 2 - Amendment No. 149

Containment Air Locks 3.6.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One or more --- -------------- NOTES--------

containment air locks I. Required Actions B. 1, B.2, with containment air and B.3 are not applicable lock interlock if both doors in the same air mechanism inoperable. lock are inoperable and Condition C is entered.

2. Entry and exit of containment is permissible under the control of a dedicated individual.

B. 1 Verify an OPERABLE 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months door is closed in the affected air lock.

AND B.2 Lock an OPERABLE door 24 hours1 days 0.143 weeks 0.0329 months closed in the affected air lock.

AND B.3 ----------- NOTE------

Air lock doors in high radiation areas may be verified locked closed by administrative means.

Verify an OPERABLE Once per 31 days door is locked closed in the affected air lock.

Prairie Island Unit 1 -Amendment No. 158 Units I and 2 3.6.2-4 Unit 2 - Amendment No. 149

Containment Air Locks 3.6.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One or more C. I Initiate action to evaluate Immediately containment air locks overall containment leakage inoperable for reasons rate per LCO 3.6.1.

other than Condition A or B. AND C.2 Verify a door is closed in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months the affected air lock.

AND C.3 Restore air lock to 24 hours1 days 0.143 weeks 0.0329 months OPERABLE status.

D. Required Action and D.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND D.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months Prairie Island Unit I - Amendment No. 158 Units 1 and 2 3.6.2-5 Unit 2 - Amendment No. 149

Containment Air Locks 3.6.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.1 ---------------- NOTES ----------------

1. An inoperable air lock door does not invalidate the previous successful performance of the overall air lock leakage test.

2. Results shall be evaluated against acceptance criteria applicable to SR 3.6.1.1.

Perform required air lock leakage rate testing in In accordance accordance with the Containment Leakage Rate with the Testing Program. Containment Leakage Rate Testing Program SR 3.6.2.2 Verify only one door in the air lock can be opened at 24 months a time.

Prairie Island Unit I - Amendment No. 158 Units I and 2 3.6.2-6 Unit 2 - Amendment No. 149

Containment Isolation Valves 3.6.3 3.6 CONTAINMENT SYSTEMS 3.6.3 Containment Isolation Valves LCO 3.6.3 Each containment isolation valve shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS

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

1. Penetration flow path(s) except for 36-inch containment purge system flow paths may be unisolated intermittently under administrative controls.

2. Separate Condition entry is allowed for each penetration flow path.

3. Enter applicable Conditions and Required Actions for systems made inoperable by containment isolation valves.

4. Enter applicable Conditions and Required Actions of LCO 3.6.1, "Containment,"

when isolation valve leakage results in exceeding the overall containment leakage rate acceptance criteria.

Prairie Island Unit 1 - Amendment No. 158 Units I and 2 3.6.3-1 Unit 2 - Amendment No. 149

Containment Isolation Valves 3.6.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A. --------- NOTE------ A.1 Isolate the affected 4 hours0.167 days 0.0238 weeks 0.00548 months Only applicable to penetration flow paths by penetration flow paths use of at least one closed with two containment and de-activated or isolation valves. mechanically blocked power operated valve, closed manual valve, blind One or more penetration flange, or check valve with flow paths with one flow through the valve containment isolation secured.

valve inoperable for reasons other than AND Condition D.

A.2 --------- NOTES------

1. Isolation devices in high radiation areas may be verified by use of administrative means.

2. Isolation devices that are locked, sealed, or otherwise secured may be verified by use of administrative means.

Verify the affected Once per 31 days penetration flow paths is for isolation isolated. devices outside containment AND L ___________________________________ J ____________________

Prairie Island Unit 1 - Amendment No. 158 Units I and 2 3.6.3-2 Unit 2 - Amendment No. 149

Containment Isolation Valves 3.6.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2 (continued) Prior to entering MODE 4 from MODE 5 if not performed within the previous 92 days for isolation devices inside containment B. -------- NOTE --------- B. I Isolate the affected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Only applicable to penetration flow path(s) by penetration flow paths use of at least one closed with two containment and de-activated power isolation valves, operated valve, closed manual valve, or blind flange.

One or more penetration flow paths with two containment isolation valves inoperable for reasons other than Condition D.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.6.3-3 Unit 2 - Amendment No. 149

Containment Isolation Valves 3.6.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. --------- NOTE------ C.1 Isolate the affected 72 hours3 days 0.429 weeks 0.0986 months Only applicable to penetration flow paths by penetration flow paths use of at least one closed with only one and de-activated power containment isolation operated valve, closed valve and a closed manual valve, or blind system. flange.

AND One or more penetration flow paths with one C.2 --------- NOTES------

containment isolation 1. Isolation devices in valve inoperable. high radiation areas may be verified by use of administrative means.

2. Isolation devices that are locked, sealed, or otherwise secured may be verified by use of administrative means.

Verify the affected Once per 31 days penetration flow paths is isolated.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.6.3-4 Unit 2 - Amendment No. 149

Containment Isolation Valves 3.6.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. One or more secondary D. 1 Restore leakage within 4 hours0.167 days 0.0238 weeks 0.00548 months containment bypass limit.

leakage or inservice purge valve(s) leakage not within limit.

E. Containment purge blind E. I Restore leakage within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months flange or inservice purge limit.

blind flange leakage not within limit.

F. Required Action and F.I Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND F.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.6.3-5 Unit 2 - Amendment No. 149

Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.1 Verify each 36-inch containment purge penetration Prior to entering blind flange is installed. MODE 4 from MODE 5 SR 3.6.3.2 Verify each 18-inch containment inservice purge After each use of penetration is blind flanged and meets SR 3.6. 1.1. the 18-inch containment inservice purge system SR 3.6.3.3 -------------------- NOTE -----------------

Valves and blind flanges in high radiation areas may be verified by use of administrative means.

Verify each containment isolation manual valve and 92 days blind flange that is located outside containment and not locked, sealed, or otherwise secured and required to be closed during accident conditions is closed, except for containment isolation valves that are open under administrative controls.

SR 3.6.3.4 -------------------- NOTE -----------------

Valves and blind flanges in high radiation areas may be verified by use of administrative means.

Verify each containment isolation manual valve and Prior to entering blind flange that is located inside containment and MODE 4 from not locked, sealed, or otherwise secured and required MODE 5 if not to be closed during accident conditions is closed, performed within except for containment isolation valves that are open the previous under administrative controls. 92 days Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.6.3-6 Unit 2 - Amendment No. 149

Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.3.5 Verify the isolation time of each automatic power In accordance operated containment isolation valve is within limits, with the Inservice Testing Program SR 3.6.3.6 Perform leakage rate testing for 18 inch Prior to system containment inservice purge valves with resilient use seals.

SR 3.6.3.7 Verify each automatic containment isolation valve 24 months that is not locked, sealed or otherwise secured in position, actuates to the isolation position on an actual or simulated actuation signal.

SR 3.6.3.8 Verify the combined leakage rate for all secondary In accordance containment bypass leakage paths is in accordance with the with the Containment Leakage Rate Testing Program. Containment Leakage Rate Testing Program Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.6.3-7 Unit 2 - Amendment No. 149

Containment Pressure 3.6.4 3.6 CONTAINMENT SYSTEMS 3.6.4 Containment Pressure LCO 3.6.4 Containment pressure shall be :< 2.0 psig.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Containment pressure not A. 1 Restore containment 8 hours0.333 days 0.0476 weeks 0.011 months within limits, pressure to within limits.

B. Required Action and B.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.1 Verify containment pressure is within limits. 12 hours0.5 days 0.0714 weeks 0.0164 months Prairie Island Unit I - Amendment No. 158 Units I and 2 3.6.4-1 Unit 2 - Amendment No. 149

Containment Spray and Cooling Systems 3.6.5 3.6 CONTAINMENT SYSTEMS 3.6.5 Containment Spray and Cooling Systems LCO 3.6.5 Two containment spray trains and two containment cooling trains shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One containment spray A. I Restore containment spray 72 hours3 days 0.429 weeks 0.0986 months train inoperable, train to OPERABLE status.

AND 10 days from discovery of failure to meet the LCO B. Required Action and B.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time of Condition A not AND met.

B.2 Be in MODE 5. 84 hours3.5 days 0.5 weeks 0.115 months Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.6.5-1 Unit 2 - Amendment No. 149

Containment Spray and Cooling Systems 3.6.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One containment cooling C.1 Restore containment 7 days train inoperable, cooling train to OPERABLE status. AND 10 days from discovery of failure to meet the LCO D. Required Action and D.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time of Condition C not AND met.

D.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.6.5-2 Unit 2 - Amendment No. 149

Containment Spray and Cooling Systems 3.6.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.1 Verify each containment spray manual, power 31 days operated, and automatic valve in the flow path that is not locked, sealed, or otherwise secured in position is in the correct position.

SR 3.6.5.2 Operate each containment cooling train fan coil unit 31 days on low motor speed for > 15 minutes.

SR 3.6.5.3 Verify each containment cooling train cooling water 24 months flow rate to each fan coil unit is > 900 gpm.

SR 3.6.5.4 Verify each containment spray pump's developed In accordance head at the flow test point is greater than or equal to with the the required developed head. Inservice Testing Program SR 3.6.5.5 Verify each automatic containment spray valve in the 24 months flow path that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.

SR 3.6.5.6 Verify each containment spray pump starts 24 months automatically on an actual or simulated actuation signal.

Prairie Island Unit 1 - Amendment No. 158 Units I and 2 3.6.5-3 Unit 2 - Amendment No. 149

Containment Spray and Cooling Systems 3.6.5 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.5.7 Verify each containment cooling train starts 24 months automatically on an actual or simulated actuation signal.

SR 3.6.5.8 Verify each spray nozzle is unobstructed. 10 years Prairie Island Unit 1 -Amendment No. 158 Units 1 and 2 3.6.5-4 Unit 2 - Amendment No. 149

Spray Additive System 3.6.6 3.6 CONTAINMENT SYSTEMS 3.6.6 Spray Additive System LCO 3.6.6 The Spray Additive System shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Spray Additive System A.l Restore Spray Additive 24 hours1 days 0.143 weeks 0.0329 months inoperable. System to OPERABLE status.

B. Required Action and B.I Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND B.2 Be in MODE 5. 84 hours3.5 days 0.5 weeks 0.115 months I I Prairie Island Unit 1 - Amendment No. 158 Units I and 2 3.6.6-1 Unit 2 - Amendment No. 149

Spray Additive System 3.6.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.6.1 Verify each spray additive manual, power operated, 31 days and automatic valve in the flow path that is not locked, sealed, or otherwise secured in position is in the correct position.

SR 3.6.6.2 Verify spray additive tank solution volume 184 days is _>2590 gal (89%).

SR 3.6.6.3 Verify spray additive tank NaOH solution 184 days concentration is > 9% and < 11% by weight.

SR 3.6.6.4 Verify each spray additive automatic valve in the 24 months flow path that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.6.6-2 Unit 2 - Amendment No. 149

Hydrogen Recombiners 3.6.7 3.6 CONTAINMENT SYSTEMS 3.6.7 Hydrogen Recombiners LCO 3.6.7 Two hydrogen recombiners shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One hydrogen A. --------- NOTE-------

recombiner inoperable. LCO 3.0.4 is not applicable.

Restore hydrogen 30 days recombiner to OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.6.7-1 Unit 2 - Amendment No. 149

Hydrogen Recombiners 3.6.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.7.1 Perform a system functional test for each hydrogen 24 months recombiner.

SR 3.6.7.2 Visually examine each hydrogen recombiner 24 months enclosure and verify there is no evidence of abnormal conditions.

SR 3.6.7.3 Perform a resistance to ground test for each heater 24 months phase.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.6.7-2 Unit 2 - Amendment No. 149

Vacuum Breaker System 3.6.8 3.6 CONTAINMENT SYSTEMS 3.6.8 Vacuum Breaker System LCO 3.6.8 Two vacuum breaker trains shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Vacuum relief function of A.1 Restore vacuum breaker 7 days one or both valves in one train to OPERABLE status.

vacuum breaker train inoperable.

B. Required Action and B.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months Prairie Island Unit 1 - Amendment No. 158 Units I and 2 3.6.8-1 Unit 2 - Amendment No. 149

Vacuum Breaker System 3.6.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.8.1 Verify each vacuum breaker train opens on an actual 92 days or simulated containment vacuum equal to or less than 0.5 psi and closes on an actual or simulated containment isolation signal.

SR 3.6.8.2 Perform CHANNEL CALIBRATION. 24 months Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.6.8-2 Unit 2 - Amendment No. 149

SBVS 3.6.9 3.6 CONTAINMENT SYSTEMS 3.6.9 Shield Building Ventilation System (SBVS)

LCO 3.6.9 Two SBVS trains shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One SBVS train A.1 Restore SBVS train to 7 days inoperable. OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.9.1 Operate each SBVS train for > 10 continuous hours 31 days with heaters operating.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.6.9-1 Unit 2 - Amendment No. 149

SBVS 3.6.9 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.9.2 Perform required SBVS filter testing in accordance In accordance with the Ventilation Filter Testing Program (VFTP). with the VFTP SR 3.6.9.3 Verify each SBVS train actuates on an actual or 24 months simulated actuation signal.

SR 3.6.9.4 Verify SBVS isolation dampers actuate on an actual 24 months or simulated signal.

Prairie Island Unit 1 -Amendment No. 158 Units 1 and 2 3.6.9-2 Unit 2 - Amendment No. 149

Shield Building 3.6.10 3.6 CONTAINMENT SYSTEMS 3.6.10 Shield Building LCO 3.6.10 The shield building shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Shield building A. 1 Restore shield building to 24 hours1 days 0.143 weeks 0.0329 months inoperable. OPERABLE status.

B. Required Action and B.! Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.6.10-1 Unit 2 - Amendment No. 149

Shield Building 3.6.10 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.10.1 Verify one shield building access door in each 31 days access opening is closed.

SR 3.6.10.2 Verify each Shield Building Ventilation System 31 days (SBVS) train OPERABLE and produces a pressure equal to or more negative than -2.00 inches water gauge and maintains a pressure equal to or more negative than -1.82 inches water gauge in the annulus.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.6.10-2 Unit 2 - Amendment No. 149

MSSVs 3.7.1 3.7 PLANT SYSTEMS 3.7.1 Main Steam Safety Valves (MSSVs)

LCO 3.7.1 Five MSSVs per steam generator shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One MSSV inoperable. A.1 Restore inoperable MSSV 4 hours0.167 days 0.0238 weeks 0.00548 months to OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND B.2 Be in MODE 4. 12 hours0.5 days 0.0714 weeks 0.0164 months Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.7.1-1 Unit 2 - Amendment No. 149

MSSVs 3.7.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.1.1 NOTE ----------------

Only required to be performed in MODES 1 and 2.

Verify each MSSV lift setpoint per Table 3.7.1-1 in In accordance accordance with the Inservice Testing Program. with the Following testing, lift setting shall be within + 1%. Inservice Testing Program Prairie Island Unit 1 - Amendment No. 158 Units I and 2 3.7.1-2 Unit 2 - Amendment No. 149

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

Main Steam Safety Valve Lift Settings VALVE NUMBER Unit I Unit 2 LIFT SETTING Steam Generator: Steam Generator: (psig + 3%)

11 #12 #21 #22 RS-21 -1 RS-21-6 RS-21 -11 RS-21-16 1077 RS-21-2 RS-21-7 RS-21-12 RS-21-17 1093 RS-21-3 RS-21-8 RS-21-13 RS-21-18 1110 RS-21-4 RS-21-9 RS-21-14 RS-21-19 1120 RS-21-5 RS-21 -10 RS-21-15 RS-21-20 1131 Prairie Island Unit I - Amendment No. 158 Units I and 2 3.7.1-3 Unit 2 - Amendment No. 149

NISIVs 3.7.2 3.7 PLANT SYSTEMS 3.7.2 Main Steam Isolation Valves (MSIVs)

LCO 3.7.2 Two MSIVs shall be OPERABLE.

APPLICABILITY: MODE 1, MODES 2 and 3 except when both MSIVs are closed.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One MSIV inoperable in A.1 Restore MSIV to 8 hours0.333 days 0.0476 weeks 0.011 months MODE 1. OPERABLE status.

B. Required Action and B.l Be in MODE 2. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time of Condition A not met.

C. --------- NOTE ---------- C.1 Close MSIV. 8 hours0.333 days 0.0476 weeks 0.011 months Separate Condition entry is allowed for each AND MSIV.

C.2 Verify MSIV is closed. Once per 7 days One or more MSIVs inoperable in MODE 2 or 3.

Prairie Island Unit I - Amendment No. 158 Units 1 and 2 3.7.2-1 Unit 2 - Amendment No. 149

MSIVs 3.7.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time of Condition C not AND met.

D.2 Be in MODE 4. 12 hours0.5 days 0.0714 weeks 0.0164 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.2.1 -------------------- NOTE ---------------------------

Only required to be performed in MODES I and 2.

Verify the isolation time of each MSIV is In accordance

< 5.0 seconds. with the Inservice Testing Program SR 3.7.2.2 -------------------- NOTE- ----------------

Only required to be performed in MODES I and 2.

Verify each MSIV actuates to the isolation position 24 months on an actual or simulated actuation signal.

Prairie Island Unit I -Amendment No. 158 Units 1 and 2 3.7.2-2 Unit 2 - Amendment No. 149

MFRVs and MFRV Bypass Valves 3.7.3 3.7 PLANT SYSTEMS 3.7.3 Main Feedwater Regulation Valves (MFRVs) and MFRV Bypass Valves LCO 3.7.3 Two MFRVs and two MFRV bypass valves shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS N OTE OTE---------------------------

1. Separate Condition entry is allowed for each valve.

2. LCO 3.0.4 is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or both MFRVs A. 1 Close and place in manual 72 hours3 days 0.429 weeks 0.0986 months inoperable, or isolate flow through MFRV(s).

AND A.2 Verify MFRV(s) closed and Once per 7 days in manual or flow through MFRV(s) isolated.

Prairie Island Unit 1 - Amendment No. 158 Units I and 2 3.7.3-1 Unit 2 - Amendment No. 149

MFRVs and MFRV Bypass Valves 3.7.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One or both MFRV B.1 Close and place in manual 72 hours3 days 0.429 weeks 0.0986 months bypass valves inoperable, or isolate flow through bypass valve(s).

AND B.2 Verify bypass valve(s) Once per 7 days closed and in manual or flow through valve(s) isolated.

C. Required Action and C.I Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND C.2 Be in MODE 4. 12 hours0.5 days 0.0714 weeks 0.0164 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.3.1 Verify the isolation time of each MFRV and MFRV In accordance bypass valve is within limits, with the Inservice Testing Program SR 3.7.3.2 Verify each MFRV and MFRV bypass valve actuates 24 months to the isolation position on an actual or simulated actuation signal.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.7.3-2 Unit 2 - Amendment No. 149

SG PORVs 3.7.4 3.7 PLANT SYSTEMS 3.7.4 Steam Generator (SG) Power Operated Relief Valves (PORVs)

LCO 3.7.4 Two SG PORV lines shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3, MODE 4 when steam generator is relied upon for heat removal.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One SG PORV line A.1 ---------- NOTE------

inoperable. LCO 3.0.4 is not applicable.

Restore SG PORV line to 7 days OPERABLE status.

B. Two SG PORV lines B.1 Restore one SG PORV line 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable, to OPERABLE status.

C. Required Action and C.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND C.2 Be in MODE 4 without 12 hours0.5 days 0.0714 weeks 0.0164 months reliance upon steam generator for heat removal.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.7.4-1 Unit 2 - Amendment No. 149

SG PORVs 3.7.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.1 Verify one complete cycle of each SG PORV. In accordance with the Inservice Testing Program SR 3.7.4.2 Verify one complete manual cycle of each SG PORV 24 months block valve.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.7.4-2 Unit 2 - Amendment No. 149

AFW System 3.7.5 3.7 PLANT SYSTEMS 3.7.5 Auxiliary Feedwater (AFW) System LCO 3.7.5 Two AFW trains shall be OPERABLE.

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

1. AFW train(s) may be considered OPERABLE during alignment and operation for steam generator level control, if it is capable of being manually realigned to the AFW mode of operation.

2. Only the AFW train which includes the motor driven pump is required to be OPERABLE in MODE 4.

APPLICABILITY: MODES 1, 2, and 3, MODE 4 when steam generator is relied upon for heat removal.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.7.5-1 Unit 2 - Amendment No. 149

AFW System 3.7.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One steam supply to A.1 Restore affected equipment 7 days turbine driven AFW to OPERABLE status.

pump inoperable. AND OR 10 days from discovery of

-NOTE failure to meet the Only applicable if MODE LCO 2 has not been entered following refueling.

One turbine driven AFW pump inoperable in MODE 3 following refueling.

B. One AFW train B. I Restore AFW train to 72 hours3 days 0.429 weeks 0.0986 months inoperable in MODE 1, 2, OPERABLE status.

or 3 for reasons other AND than Condition A.

10 days from discovery of failure to meet the LCO Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.7.5-2 Unit 2 - Amendment No. 149

AFW System 3.7.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time for Condition A AND or B not met.

C.2 Be in MODE 4. 12 hours0.5 days 0.0714 weeks 0.0164 months D. Two AFW trains D.1 ---------- NOTE------

inoperable in MODE 1, 2, LCO 3.0.3 and all other or 3. LCO Required Actions requiring MODE changes are suspended until one AFW train is restored to OPERABLE status.

Initiate action to restore Immediately one AFW train to OPERABLE status.

E. Required AFW train E.1 Initiate action to restore Immediately inoperable in MODE 4. AFW train to OPERABLE status.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.7.5-3 Unit 2 - Amendment No. 149

AFW System 3.7.5 SURVEILLANCE REQUIREMENTS I SURVEILLANCE FREQUENCY SR 3.7.5.1 NOTE -----------------

AFW train(s) may be considered OPERABLE during alignment and operation for steam generator level control if it is capable of being manually realigned to the AFW mode of operation.

Verify each AFW manual, power operated, and 31 days automatic valve in each water flow path, and in both steam supply flow paths to the steam turbine driven pump, that is not locked, sealed, or otherwise secured in position, is in the correct position.

i SR 3.7.5.2 NOTE -----------------

Not required to be performed for the turbine driven AFW pump until prior to exceeding 10% RTP or within 72 hours3 days 0.429 weeks 0.0986 months after RCS temperature > 350'F.

Verify the developed head of each AFW pump at the In accordance flow test point is greater than or equal to the required with the Inservice developed head. Testing Program Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.7.5-4 Unit 2 - Amendment No. 149

AFW System 3.7.5 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY i

SR 3.7.5.3 NOTE ----------------

AFW train(s) may be considered OPERABLE during alignment and operation for steam generator level control, if it is capable of being manually realigned to the AFW mode of operation.

Verify each AFW automatic valve that is not locked, 24 months sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.

i SR 3.7.5.4 N OTES ---------------------------

1. Not required to be performed for the turbine driven AFW pump until prior to exceeding 10% RTP or within 72 hours3 days 0.429 weeks 0.0986 months after RCS temperature > 350 0 F.

2. AFW train(s) may be considered OPERABLE during alignment and operation for steam generator level control, if it is capable of being manually realigned to the AFW mode of operation.

Verify each AFW pump starts automatically on an 24 months actual or simulated actuation signal.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.7.5-5 Unit 2 - Amendment No. 149

CSTs 3.7.6 3.7 PLANT SYSTEMS 3.7.6 Condensate Storage Tanks (CSTs)

LCO 3.7.6 The CSTs shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3, MODE 4 when steam generator is relied upon for heat removal.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. CSTs inoperable. A. 1 Verify by administrative 4 hours0.167 days 0.0238 weeks 0.00548 months means OPERABILITY of backup water supply. AND Once per 12 hours0.5 days 0.0714 weeks 0.0164 months thereafter AND A.2 Restore CSTs to 7 days OPERABLE status.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.7.6-1 Unit 2 - Amendment No. 149

CSTs 3.7.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND B.2 Be in MODE 4, without 12 hours0.5 days 0.0714 weeks 0.0164 months reliance on steam generator for heat removal.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.6.1 Verify CSTs useable contents _>100,000 gal per 12 hours0.5 days 0.0714 weeks 0.0164 months operating unit.

Prairie Island Unit 1 - Amendment No. 158 Units I and 2 3.7.6-2 Unit 2 - Amendment No. 149

CC System 3.7.7 3.7 PLANT SYSTEMS 3.7.7 Component Cooling Water (CC) System LCO 3.7.7 Two CC trains shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One CC train inoperable. A.1 ---------- NOTE------

Enter applicable Conditions and Required Actions of LCO 3.4.6, "RCS Loops MODE 4," for residual heat removal loops made inoperable by CC.

Restore CC train to 72 hours3 days 0.429 weeks 0.0986 months OPERABLE status.

B. Required Action and B. 1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time of Condition A not AND met.

B.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.7.7-1 Unit 2 - Amendment No. 149

CC System 3.7.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.7.1 ---------------- NOTE ----------------

Isolation of CC flow to individual components does not render the CC System inoperable.

Verify each CC manual, power operated, and 31 days automatic valve in the flow path servicing safety related equipment, that is not locked, sealed, or otherwise secured in position, is in the correct position.

SR 3.7.7.2 ----------------- NOTE ----------------

This SR only applies to those valves required to align CC System to support the safety injection or recirculation phase of emergency core cooling.

Verify each CC automatic valve in the flow path that 24 months is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.

SR 3.7.7.3 Verify each CC pump starts automatically on an 24 months actual or simulated actuation signal.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.7.7-2 Unit 2 - Amendment No. 149

CL System 3.7.8 3.7 PLANT SYSTEMS 3.7.8 Cooling Water (CL) System LCO 3.7.8 Two CL trains shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. No safeguards CL pumps ------------ NOTES---------

OPERABLE for one 1. Unit I enter applicable train. Conditions and Required Actions of LCO 3.8.1, "AC Sources-MODES 1, 2, 3, and 4," for emergency diesel generator made inoperable ty CL System.

2. Both units enter applicable Conditions and Required Actions of LCO 3.4.6, "RCS Loops-MODE 4," for residual heat removal loops made inoperable by CL System.

3. This Condition may not exist

> 7 days in any consecutive 30 day period.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.7.8-1 Unit 2 - Amendment No. 149

CL System 3.7.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME

i. i A. (continued) A.I Restore one safeguards CL 7 days pump to OPERABLE status.

AND 10 days from discovery of failure to meet the LCO 4 I B. One CL supply header NOTES-----------------

inoperable. 1. Unit 1 enter applicable Conditions and Required Actions of LCO 3.8.1, "AC Sources-MODES 1, 2, 3, and 4," for emergency diesel generator made inoperable by CL System.

2. Both units enter applicable Conditions and Required Actions of LCO 3.4.6, "RCS Loops-MODE 4," for residual heat removal loops made inoperable by CL System.

B.1 Verify vertical motor driven 4 hours0.167 days 0.0238 weeks 0.00548 months CL pump OPERABLE.

AND

____________________________ I ________________________________

Prairie Island Unit 1 - Amendment No. 158 Units I and 2 3.7.8-2 Unit 2 - Amendment No. 149

CL System 3.7.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.2 Verify opposite train diesel 4 hours0.167 days 0.0238 weeks 0.00548 months driven CL pump OPERABLE.

AND B.3 Restore CL supply header to 72 hours3 days 0.429 weeks 0.0986 months OPERABLE status.

AND 10 days from discovery of failure to meet the LCO C. Required Action and C. 1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND C.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months D. Diesel driven CL pumps D. I Restore fuel oil supply to 48 hours2 days 0.286 weeks 0.0658 months stored fuel oil supply within limits.

< 19,500 gal and AND

> 17,000 gal.

9 days from discovery of failure to meet the LCO Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.7.8-3 Unit 2 - Amendment No. 149

CL System 3.7.8 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME 4 I-E. Diesel driven CL pumps E. 1 Declare diesel driven CL Immediately stored ftiel oil supply pumps inoperable.

< 17,000 gal.

OR Required Action and associated Completion Time of Condition D not met.

-I _______________________________________________________________________

SUJRVEILLANCE REOUIREMENTS SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY i

SR 3.7.8.1 ---------------------------- NOTE--------------------

Isolation of CL flow to individual components does not render the CL System inoperable.

Verify each CL System manual, power operated, and 31 days automatic valve in the flow path servicing safety related equipment, that is not locked, sealed, or otherwise secured in position, is in the correct position.

SR 3.7.8.2 Verify each diesel driven CL pump starts and 31 days assumes load within one minute.

Prairie Island Unit 1 Amendment No. 158 Units I and 2 3.7.8-4 Unit 2 - Amendment No. 149

CL System 3.7.8 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.7.8.3 Verify stored diesel driven CL pumps fuel oil supply 31 days

> 19,500 gal.

SR 3.7.8.4 Verify OPERABILITY of vertical motor driven CL 92 days pump.

SR 3.7.8.5 Verify each CL System automatic valve required to 24 months mitigate accidents that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.

SR 3.7.8.6 Verify the diesel driven and vertical motor driven CL 24 months pumps start automatically on an actual or simulated actuation signal.

Prairie Island Unit I - Amendment No. 158 Units 1 and 2 3.7.8-5 Unit 2 - Amendment No. 149

Emergency CL Supply 3.7.9 3.7 PLANT SYSTEMS 3.7.9 Emergency Cooling Water (CL) Supply LCO 3.7.9 The Emergency CL supply shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One safeguards traveling A. --------- NOTE------

screen inoperable. Not applicable during periods of testing for !<24 hours1 days 0.143 weeks 0.0329 months .

Verify one emergency bay 4 hours0.167 days 0.0238 weeks 0.00548 months sluice gate open.

AND A.2 Restore safeguards traveling 90 days screen to OPERABLE status.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.7.9-1 Unit 2 - Amendment No. 149

Emergency CL Supply 3.7.9 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME I- I.

B. Both safeguards traveling B..1 Verify one emergency bay 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months screens inoperable. sluice gate open.

AND B.2 Restore one safeguards 7 days traveling screen to OPERABLE status.

f t C. Emergency CL Line C. 1 Verify one emergency bay 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. sluice gate open.

AND C.2 Restore Emergency CL 7 days Line to OPERABLE status.

D. Required Action and D.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND D.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.7.9-2 Unit 2 - Amendment No. 149

Emergency CL Supply 3.7.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.9.1 Verify safeguards traveling screens OPERABLE. 92 days Prairie Island Unit 1 - Amendment No. 158 Units I and 2 3.7.9-3 Unit 2 - Amendment No. 149

CRSVS 3.7.10 3.7 PLANT SYSTEMS 3.7.10 Control Room Special Ventilation System (CRSVS)

LCO 3.7.10 Two CRSVS trains shall be OPERABLE.

NOTE The control room boundary may be opened intermittently under administrative control.

APPLICABILITY: MODES 1, 2, 3, and 4, During movement of irradiated fuel assemblies.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One CRSVS train A.1 Restore CRSVS train to 7 days inoperable. OPERABLE status.

B. Two CRSVS trains B. 1 Restore control room 24 hours1 days 0.143 weeks 0.0329 months inoperable due to boundary to OPERABLE inoperable control room status.

boundary in MODES 1, 2, 3, or4.

Prairie Island Unit I - Amendment No. 158 Units 1 and 2 3.7.10-1 Unit 2 - Amendment No. 149

CRSVS 3.7.10 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time of Condition A not AND met in MODE 1, 2, 3, or

4. C.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months D. Required Action and D.1 Place OPERABLE CRSVS Immediately associated Completion train in operation.

Time of Condition A not met during movement of OR irradiated fuel assemblies.

D.2 Suspend movement of Immediately irradiated fuel assemblies.

E. Two CRSVS trains E.I Suspend movement of Immediately inoperable during irradiated fuel assemblies.

movement 4f irradiated fuel assemblies.

F. Two CRSVS trains F.1 Enter LCO 3.0.3. Immediately inoperable in MODE 1, 2, 3, or 4 for reasons other than Condition B.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.7.10-2 Unit 2 - Amendment No. 149

CRSVS 3.7.10 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.10.1 Operate each CRSVS train _>15 minutes. 31 days SR 3.7.10.2 Perform required CRSVS filter testing in In accordance accordance with the Ventilation Filter Testing with VFTP Program (VFTP).

SR 3.7.10.3 Verify each CRSVS train actuates on an actual or 24 months simulated actuation signal.

SR 3.7.10.4 Verify the CRSVS fan in each train delivers 3600 24 months on a to 4400 cfm. STAGGERED TEST BASIS Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.7.10-3 Unit 2 - Amendment No. 149

SCWS 3.7.11 3.7 PLANT SYSTEMS 3.7.11 Safeguards Chilled Water System (SCWS)

LCO 3.7.11 Two SCWS loops shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4, During movement of irradiated fuel assemblies.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One SCWS loop A.1 Restore SCWS loop to 30 days inoperable. OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time of Condition A not AND met in MODE 1, 2, 3, or 4. B.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.7.11-1 Unit 2 - Amendment No. 149

SCWS 3.7.11 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C. 1 Place OPERABLE SCWS Immediately associated Completion loop in operation.

Time of Condition A not met during movement of OR irradiated fuel assemblies.

C.2 Suspend movement of Immediately irradiated fuel assemblies.

D. Two SCWS loops D. 1 Suspend movement of Immediately inoperable during irradiated fuel assemblies.

movement of irradiated fuel assemblies.

E. Two SCWS loops E.1 Enter LCO 3.0.3. Immediately inoperable in MODE 1, 2, 3, or 4.

Prairie Island Unit 1 - Amendment No. 158 Units I and 2 3.7.11-2 Unit 2 - Amendment No. 149

SCWS 3.7.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.11.1 Verify each SCWS loop actuates on an actual or 24 months on a simulated actuation signal. STAGGERED TEST BASIS SR 3.7.11.2 Verify SCWS components OPERABLE in In accordance accordance with the Inservice Testing Program. with the Inservice Testing Program Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.7.11-3 Unit 2 - Amendment No. 149

ABSVS 3.7.12 3.7 PLANT SYSTEMS 3.7.12 Auxiliary Building Special Ventilation System (ABSVS)

LCO 3.7.12 Two ABSVS trains shall be OPERABLE.

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

The ABSVS boundary may be opened under administrative control.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One ABSVS train A.1 Restore ABSVS train to 7 days inoperable. OPERABLE status.

B. Two ABSVS trains B. 1 Restore ABSVS boundary 24 hours1 days 0.143 weeks 0.0329 months inoperable due to to OPERABLE status.

inoperable ABSVS boundary.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.7.12-1 Unit 2 - Amendment No. 149

ABSVS 3.7.12 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.I Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND C.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.12.1 Operate each ABSVS train for > 10 hours0.417 days 0.0595 weeks 0.0137 months with 31 days the heaters operating.

SR 3.7.12.2 Perform required ABSVS filter testing in In accordance accordance with the Ventilation Filter Testing with the VFTP Program (VFTP).

SR 3.7.12.3 Verify each ABSVS train can produce a negative 92 days pressure within 6 minutes after initiation.

SR 3.7.12.4 Verify each ABSVS train actuates on an actual or 24 months simulated actuation signal.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.7.12-2 Unit 2 - Amendment No. 149

SFPSVS 3.7.13 3.7 PLANT SYSTEMS 3.7.13 Spent Fuel Pool Special Ventilation System (SFPSVS)

LCO 3.7.13 Two SFPSVS trains shall be OPERABLE.

APPLICABILITY: During movement of irradiated fuel assemblies in the spent fuel pool enclosure.

ACTIONS

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

LCO 3.0.3 is not applicable.

COPETO REQUIRED ACTION COMPLETION CONDITION TIME 7 days A. One SFPSVS train A. 1 Restore SFPSVS train to inoperable. CPERABLE status.

B. Required Action and B.1 Place OPERABLE SFPSVS Immediately associated Completion train in operation.

Time of Condition A not met. OR B.2 Suspend movement of Immediately irradiated fuel assemblies in the spent fuel pool enclosure.

Unit 1 - Amendment No. 158 Prairie Island Unit 2 - Amendment No. 149 Units 1 and 2 3.7.13-1

SFPSVS 3.7.13 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Both SFPSVS trains C.1 Suspend movement of Immediately inoperable, irradiated fuel assemblies in the spent fuel pool enclosure.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.13.1 Operate each SFPSVS train for >_ 10 hours0.417 days 0.0595 weeks 0.0137 months with 31 days the heaters operating.

SR 3.7.13.2 Perform required SFPSVS filter testing in In accordance accordance with the Ventilation Filter Testing with the VFTP Program (VFTP).

SR 3.7.13.3 Verify each SFPSVS train actuates on an actual or 24 months simulated actuation signal.

SR 3.7.13.4 Verify the SFPSVS fan in each train delivers 4680 24 months on a to 5720 cfm. STAGGERED TEST BASIS Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.7.13-2 Unit 2 - Amendment No. 149

Secondary Specific Activity 3.7.14 3.7 PLANT SYSTEMS 3.7.14 Secondary Specific Activity LCO 3.7.14 The specific activity of the secondary coolant shall be _<0.10 /Ci/gm DOSE EQUIVALENT 1-131.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Specific activity not A.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months within limit.

AND A.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.14.1 Verify the specific activity of the secondary coolant 31 days is _<0.10 jiCi/gm DOSE EQUIVALENT 1-131.

Prairie Island Unit I - Amendment No. 158 Units land 2 3.7.14-1 Unit 2 - Amendment No. 149

Spent Fuel Storage Pool Water Level 3.7.15 3.7 PLANT SYSTEMS 3.7.15 Spent Fuel Storage Pool Water Level LCO 3.7.15 The spent fuel storage pool water level shall be >_23 ft over the top of irradiated fuel assemblies seated in the storage racks.

APPLICABILHIY: During movement of irradiated fuel assemblies in the spent fuel storage pool.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Spent fuel storage pool A. 1 ------------- NOTE------

water level not within LCO 3.0.3 is not applicable.

lim it. ---------------------------------

Suspend movement of Immediately irradiated fuel assemblies in the spent fuel storage pool.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.15.1 Verify the spent fuel storage pool water level is 7 days

_ 23 ft above the top of the irradiated fuel assemblies seated in the storage racks.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.7.15-1 Unit 2 - Amendment No. 149

Spent Fuel Storage Pool Boron Concentration 3.7.16 3.7 PLANT SYSTEMS 3.7.16 Spent Fuel Storage Pool Boron Concentration LCO 3.7.16 The spent fuel storage pool boron concentration shall be _>1800 ppm.

APPLICABILITY: When fuel assemblies are stored in the spent fuel storage pool.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Spent fuel storage pool -------------- NOTE ---------

boron concentration not LCO 3.0.3 is not applicable.

w ith in lim it. ------------------------------------------

A. 1 Suspend movement of fuel Immediately assemblies in the spent fuel storage pool.

AND A.2 Initiate action to restore spent Immediately fuel storage pool boron concentration to within limit.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.7.16-1 Unit 2 - Amendment No. 149

Spent Fuel Storage Pool Boron Concentration 3.7.16 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.16.1 Verify the spent fuel storage pool boron 7 days concentration is within limit.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.7.16-2 Unit 2 - Amendment No. 149

Spent Fuel Pool Storage 3.7.17 3.7 PLANT SYSTEMS 3.7.17 Spent Fuel Pool Storage LCO 3.7.17 The combination of initial enrichment, burnup and decay time of each fuel assembly stored in the spent fuel pool shall be within the Unrestricted Region of Figure 3.7.17-1 or Figure 3.7.17-2, as applicable, or in accordance with Specification 4.3.1.1.

APPLICABILITY: Whenever any fuel assembly is stored in the spent fuel storage pool.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of the LCO A.1 --------- NOTE------

not met. LCO 3.0.3 is not applicable.

Initiate action to move the Immediately noncomplying fuel assembly to an acceptable location.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.7.17-1 Unit 2 - Amendment No. 149

Spent Fuel Pool Storage 3.7.17 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.17.1 Verify by administrative means the initial Prior to storing enrichment, burnup and decay time of the fuel or moving the assembly is in accordance with Figure 3.7.17-1 or fuel assembly Figure 3.7.17-2, as applicable, or Specification 4.3.1.1.

SR 3.7.17.2 Verify spent fuel pool inventory. Within 7 days after completion of a spent fuel pool fuel handling campaign Prairie Island Unit 1 - Amendment No. 158 Units I and 2 3.7.17-2 Unit 2 - Amendment No. 149

Spent Fuel Pool Storage 3.7.17 40000 I III I iI___i I

- _ I __

_ 1 0 Years 35000 5 Years I 1. 1 I I/ 10 Years I r.// 15 Years 20 Years 30000 UNRESTRICTED !-//

- -t- ! ,

25000 - ----- --- ----- .- v-/ -/

0. I ///

- -- -- -- - - - - - - -,, - ,1 1~

20000 ----- ---- --- / 1

///-i Q) ///-/

- - - - -/ - -/

15000 -. I ! !

-. 11 I

///

100040 I - -4.- 4- - - f-+ - I - - - - - T - I - T- T- T -

RESTRICTED 500 0--

-++ - ~*1~~

o ----

/~zrzzIL 1.0 2.0 3.0 4.0 5.0 Initial U-235 Enrichment (w/o)

Figure 3.7.17-1 Spent Fuel Pool Unrestricted Region Burnup and Decay Time Requirements-OFA Fuel Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.7.17-3 Unit 2 - Amendment No. 149

Spent Fuel Pool Storage 3.7.17 40000 0 Years 5 Years 35000 10 Years 15 Years

/I /A/ 20 Years E

a25 30 000 000 I JUNRESTRICTED {I

-1fl m

S20 nfnl , - -i 1 1 1 1 -,' - , +. - -

I -- I-I ,,

AA*

IL

/,4///

MW IIIII 15 V*V 000, 0/"1 F/M, r4 . MY-IIIr 1 000 + - - C - - - f -f-I I

71f I-- -T RIlT RESTRICTED 500( 0_

?-

0 r

- -- ~If - -

1.0 2.0 3.0 4.0 5.0 Initial U-235 Enrichment (w/o)

Figure 3.7.17-2 Spent Fuel Pool Unrestricted Region Burnup and Decay Time Requirements-STD Fuel Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.7.17-4 Unit 2 - Amendment No. 149

AC Sources-Operating 3.8.1 3.8 ELECTRICAL POWER SYSTEMS 3.8.1 AC Sources-Operating LCO 3.8.1 The following AC electrical sources shall be OPERABLE:

a. Two paths between the offsite transmission grid and the onsite 4 kV Safeguards Distribution System; and

b. Two diesel generators (DGs) capable of supplying the onsite 4 kV Safeguards Distribution System.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS A. One path inoperable. A. 1 Perform SR 3.8.1.1 for the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months OPERABLE path.

AND Once per 8 hours0.333 days 0.0476 weeks 0.011 months thereafter AND A.2 Restore path to 7 days OPERABLE status.

AND 14 days from discovery of failure to meet LCO Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.8.1-1 Unit 2 - Amendment No. 149

AC Sources-Operating 3.8.1 ACTIONS (continued')

CONDITION REQUIRED ACTION COMPLETION TIME B. One DG inoperable. B. I Perform SR 3.8.1.1 for the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months paths.

AND Once per 8 hours0.333 days 0.0476 weeks 0.011 months thereafter AND B.2 Declare required feature(s) 4 hours0.167 days 0.0238 weeks 0.00548 months from supported by the discovery of inoperable DG inoperable Condition B when its required concurrent with redundant feature(s) is inoperability of inoperable. redundant required feature(s)

AND B.3.1 Determine OPERABLE 24 hours1 days 0.143 weeks 0.0329 months DG is not inoperable due to common cause failure.

OR

___________________________________ J _______________________________________ a Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.8.1-2 Unit 2 - Amendment No. 149

AC Sources-Operating 3.8.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.3.2 Perform SR 3.8.1.2 for 24 hours1 days 0.143 weeks 0.0329 months OPERABLE DG.

AND B.4 Restore DG to 7 days OPERABLE status.

AND 14 days from discovery of failure to meet LCO C. Two paths inoperable. C. 1 Declare required feature(s) 12 hours0.5 days 0.0714 weeks 0.0164 months from inoperable when its discovery of redundant required Condition C feature(s) is inoperable, concurrent with inoperability of redundant required features AND C.2 Restore one path to 24 hours1 days 0.143 weeks 0.0329 months OPERABLE status.

Prairie Island Unit I - Amendment No. 158 Units 1 and 2 3.8.1-3 Unit 2 - Amendment No. 149

AC Sources-Operating 3.8.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. One path inoperable. - ------------- NOTE ---------

Enter applicable Conditions and AND Required Actions of LCO 3.8.9, "Distribution Systems One DG inoperable. Operating," when Condition D is entered with no AC power source to either train.

D. I Restore path to 12 hours0.5 days 0.0714 weeks 0.0164 months OPERABLE status.

OR D.2 Restore DG to 12 hours0.5 days 0.0714 weeks 0.0164 months OPERABLE status.

E. Two DGs inoperable. E. I Restore one DG to 2 hours0.0833 days 0.0119 weeks 0.00274 months OPERABLE status.

F. Required Action and F.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time of Condition A, B, AND C, D, or E not met.

F.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.8.1-4 Unit 2 - Amendment No. 149

AC Sources-Operating 3.8.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME G. Two DGs inoperable and G.1 Enter LCO 3.0.3. Immediately one or more paths inoperable.

OR One DG inoperable and two paths inoperable.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.8.1-5 Unit 2 - Amendment No. 149

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.1 Verify correct breaker alignment and indicated 7 days power availability for each path.

SR 3.8.1.2 -------------------- NOTES----------------

1. Performance of SR 3.8.1.6 satisfies this SR.

2. All DG starts may be preceded by an engine prelube period and followed by a warmup period prior to loading.

3. A modified DG start involving idling and gradual acceleration to synchronous speed may be used for this SR in consideration of manufacturer's recommendations. When modified start procedures are not used, the time, voltage, and frequency tolerances of SR 3.8.1.6 must be met.

Verify each DG starts from standby conditions and 31 days achieves steady state voltage >_ 3740 V and

< 4580 V, and frequency Ž! 58.8 Hz and !<61.2 Hz.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.8.1-6 Unit 2 - Amendment No. 149

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued) I FREQUENCY SURVEILLANCE i

SR 3.8.1.3 --------------------------- NOTES --------------------------

1. DG loadings may include gradual loading in consideration of manufacturer's recomendations.

2. Momentary transients outside the load range do not invalidate this test.

3. This Surveillance shall be conducted on only one DG at a time.

4. This SR shall be preceded by and immediately follow without shutdown a successful performance of SR 3.8.1.2 or SR 3.8.1.6.

Verify each DG is synchronized and loaded and 31 days operates for > 60 minutes at a load:

a. Unit 1;> 1650 kW; and

b. Unit 2;> 5100 kW and *< 5300 kW.

SR 3.8.1.4 Verify fuel oil level above lower limit switch in each 31 days day tank.

SR 3.8.1.5 Verify the fuel oil transfer system operates to transfer 31 days fuel oil from storage tank to the day tank.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.8.1-7 Unit 2 - Amendment No. 149

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.6 ---------------------------- NOTE --------------------------

All DG starts may be preceded by an engine prelube period.

Verify each DG starts from standby condition and 184 days achieves:

a. In < 10 seconds, voltage _>3740 V and frequency >_ 58.8 Hz; and

b. Steady state voltage Ž>3740 V and !<4580 V, and frequency >_ 58.8 Hz and *< 61.2 Hz.

SR 3.8.1.7 Verify each DG does not trip during and following a 24 months load rejection of:

1. Unit 1 > 650 kW; and

2. Unit 2> 860 kW.

SR 3.8.1.8 Verify each DG's automatic trips are bypassed on an 24 months actual or simulated safety injection signal except:

a. Engine overspeed;

b. Generator differential current; and

c. Ground fault (Unit 1 only).

Prairie Island Unit 1 - Amendment No. 158 Units I and 2 3.8.1-8 Unit 2 - Amendment No. 149

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued) I SURVEILLANCE FREQUENCY SR 3.8.1.9 -------------------- NOTE ----------------

Momentary transients outside the load range do not invalidate this test.

Verify each DG operates for > 24 hours1 days 0.143 weeks 0.0329 months : 24 months

a. For > 2 hours0.0833 days 0.0119 weeks 0.00274 months loaded:

Unit I > 2832 kW, and

< 3000 kW Unit 2 >_5562 kW, and

< 5940 kW; and

b. For the remaining hours of the test loaded:

Unit 1 > 2475 kW, and Unit 2 >24860 kW; and

c. Achieves steady state voltage > 3740 V and

4580 V; and frequency 58.8 Hz and < 61.2 Hz.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.8.1-9 Unit 2 - Amendment No. 149

AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY L _______________________________________________________

SR 3.8.1.10 NOTES ----------------

1. All DG starts may be preceded by an engine prelube period.

2. This Surveillance shall not be performed in MODE 1, 2, 3, or 4.

Verify on an actual or simulated loss of offsite power 24 months signal in conjunction with an actual or simulated safety injection actuation signal:

a. De-energization of emergency buses;

b. Load shedding from emergency buses; and

c. DG auto-starts from standby condition and energizes emergency loads in _<60 seconds.

SR 3.8.1.11 NOTE ----------------

All DG starts may be preceded by an engine prelube period.

Verify on an actual or simulated loss of offsite power 24 months signal that the DG auto-starts from standby condition.

Prairie Island Unit 1 -Amendment No. 158 Units 1 and 2 3.8.1-10 Unit 2 - Amendment No. 149

AC Sources - Shutdown 3.8.2 3.8 ELECTRICAL POWER SYSTEMS 3.8.2 AC Sources- Shutdown LCO 3.8.2 The following AC electrical power sources shall be OPERABLE:

a. One path between the offsite transmission grid and the onsite 4 kV Safeguards Distribution System required by LCO 3.8.10, "Distribution Systems-Shutdown "; and

b. One diesel generator (DG) capable of supplying one train of the onsite 4 kV Safeguards Distribution System required by LCO 3.8.10.

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

LCO 3.8.2 may not be applicable for a period of 8 hours0.333 days 0.0476 weeks 0.011 months during the performance of SR 3.8.1.10.

APPLICABILITY: MODES 5 and 6, During movement of irradiated fuel assemblies.

ACTIONS

N-NOTE LCO 3.0.3 not applicable.

S............................................................................................................

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.8.2-1 Unit 2 - Amendment No. 149

AC Sources - Shutdown 3.8.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A. Required path inoperable. --- - --------------- NOTE--------

Enter applicable Conditions and Required Actions of LCO 3.8.10, with one required train de-energized as a result of Condition A.

A. I Suspend CORE Immediately ALTERATIONS.

AND A.2 Suspend movement of Immediately irradiated fuel assemblies.

AND A.3 Suspend operations Immediately involving positive reactivity additions that could result in loss of required SDM or boron concentration.

AND A.4 Initiate action to restore Immediately required path to OPERABLE status.

n _____________________________________ L Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.8.2-2 Unit 2 - Amendment No. 149

AC Sources- Shutdown 3.8.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One required DG B.1 Suspend CORE Immediately inoperable. ALTERATIONS.

AND B.2 Suspend movement of Immediately irradiated fuel assemblies.

AND B.3 Suspend operations Immediately involving positive reactivity additions that could result in loss of required SDM or boron concentration.

AND B.4 Initiate action to restore Immediately required DG to OPERABLE status.

Prairie Island Unit 1 - Amendment No. 158 Units I and 2 3.8.2-3 Unit 2 - Amendment No. 149

AC Sources - Shutdown 3.8.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.2.1 ------------------- NOTE -----------------

The following SRs are not required to be performed:

SR 3.8.1.2, SR 3.8.1.3, and SR 3.8.1.7 through SR 3.8.1.10.

For AC sources required to be OPERABLE, the SRs In accordance of Specification 3.8.1, "AC Sources-Operating," are with applicable applicable. SRs Prairie Island Unit 1 - Amendment No. 158 Units I and 2 3.8.2-4 Unit 2 - Amendment No. 149

Diesel Fuel Oil 3.8.3 3.8 ELECTRICAL POWER SYSTEMS 3.8.3 Diesel Fuel Oil LCO 3.8.3 The stored diesel generator (DG) fuel oil supply shall be within limits.

APPLICABILITY: When the DG(s) is required to be OPERABLE.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Stored DG fuel oil A.l Restore fuel oil supply to 48 hours2 days 0.286 weeks 0.0658 months supply: within limits.

Unit 1 < 42,000 gal and

> 36,000 gal; Unit 2 < 75,000 gal and

> 65,000 gal.

B. One or more required DG B.1 Restore fuel oil tank(s) 7 days fuel oil tank(s) with properties to within limit(s).

stored fuel oil not within limit(s).

C. Required Action and C. 1 Isolate the associated DG 2 hours0.0833 days 0.0119 weeks 0.00274 months associated Completion fuel oil tank(s).

Time of Condition B not met.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.8.3-1 Unit 2 - Amendment No. 149

Diesel Fuel Oil 3.8.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Stored DG fuel oil ------------------ NOTE----------

supply: Enter applicable Conditions and Required Actions of LCO 3.7.8, Unit 1 < 36,000 gal; "CL System" for CL train(s) made inoperable as a result of Unit 2 < 65,000 gal. stored fuel oil properties not within limits.

OR Required Action and D. I Declare DGs inoperable. Immediately associated Completion Time of Conditions A or C not met.

_________________________________ n_____________________________________ .1_____________________

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.3.1 Verify stored DG fuel oil supply contains: 31 days Unit 1 > 42,000 gal; and Unit 2 > 75,000 gal of fuel.

SR 3.8.3.2 Verify fuel oil properties of new and stored fuel oil In accordance are tested in accordance with, and maintained within with the Diesel the limits of, the Diesel Fuel Oil Testing Program. Fuel Oil Testing Program Prairie Island Unit 1 - Amendment No. 158 Units I and 2 3.8.3-2 Unit 2 - Amendment No. 149

DC Sources - Operating 3.8.4 3.8 ELECTRICAL POWER SYSTEMS 3.8.4 DC Sources - Operating LCO 3.8.4 The Train A and Train B DC electrical power subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One battery charger A.1 Verify its associated battery 2 hours0.0833 days 0.0119 weeks 0.00274 months inoperable, is OPERABLE.

AND A.2 Verify the other train 2 hours0.0833 days 0.0119 weeks 0.00274 months battery charger is OPERABLE.

AND A.3 Verify the diesel generator 2 hours0.0833 days 0.0119 weeks 0.00274 months and safeguards equipment on the other train are OPERABLE.

AND A.4 Restore battery charger to 8 hours0.333 days 0.0476 weeks 0.011 months OPERABLE status.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.8.4-1 Unit 2 - Amendment No. 149

DC Sources - Operating 3.8.4 ACTIONS (continued)

CONDITION RFQUIRED ACTION COMPLETION TIME B. One battery B.1 Verify associated battery 2 hours0.0833 days 0.0119 weeks 0.00274 months inoperable, charger is OPERABLE.

AND B.2 Verify other train battery is 2 hours0.0833 days 0.0119 weeks 0.00274 months OPERABLE.

AND B.3 Verify other train battery 2 hours0.0833 days 0.0119 weeks 0.00274 months charger is OPERABLE.

AND B.4 Restore battery to 8 hours0.333 days 0.0476 weeks 0.011 months OPERABLE status.

C. One DC electrical C. 1 Restore DC electrical 2 hours0.0833 days 0.0119 weeks 0.00274 months power subsystem power subsystem to inoperable for reasons OPERABLE status.

other than Condition A or B.

D. Required Action and D.l Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months Associated Completion Time not met. AND D.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.8.4-2 Unit 2 - Amendment No. 149

DC Sources - Operating 3.8.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.4.1 Verify battery terminal voltage is greater than or 7 days equal to the minimum established float voltage.

SR 3.8.4.2 Verify each battery charger supplies >_250 amps at 24 months greater than or equal to the minimum established float voltage for > 4 hours0.167 days 0.0238 weeks 0.00548 months .

OR Verify each battery charger can recharge the battery to the fully charged state within 24 hours1 days 0.143 weeks 0.0329 months while supplying the demands of the various continuous steady state loads, after a battery discharge to the bounding design basis event discharge state.

SR 3.8.4.3 ------------------ NOTES -----------------

1. The modified performance discharge test in SR 3.8.6.6 may be performed in lieu of SR 3.8.4.3.

2. This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.

Verify battery capacity is adequate to supply, and 24 months maintain in OPERABLE status, the required emergency loads for the design duty cycle when subjected to a battery service test.

Prairie Island Unit 1 - Amendment No. 158 Units I and 2 3.8.4-3 Unit 2 - Amendment No. 149

DC Sources-Shutdowxn 3.8.5 3.8 ELECTRICAL POWER SYSTEMS 3.8.5 DC Sources-Shutdown LCO 3.8.5 One DC electrical power subsystem shall be OPERABLE.

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

Service Building DC electrical power subsystem components may be used to replace safeguards DC electrical power subsystem components when the required safeguards DC electrical power subsystem is inoperable due to testing, maintenance, or replacement.

APPLICABILITY: MODES 5 and 6, During movement of irradiated fuel assemblies.

ACTIONS

N O TE

OTE.............................. ------------

LCO 3.0.3 is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. One required battery A. 1 Restore battery charger to 8 hours0.333 days 0.0476 weeks 0.011 months charger inoperable. OPERABLE status.

Prairie Island Unit I - Amendment No. 158 Units 1 and 2 3.8.5-1 Unit 2 - Amendment No. 149

DC Sources-Shutdown 3.8.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One required DC B. I Suspend CORE Immediately electrical power ALTERATIONS.

subsystem inoperable for reasons other than AND Condition A.

B.2 Suspend movement of Immediately OR irradiated fuel assemblies.

Required Action and AND associated Completion Time of Condition A not B.3 Suspend operations Immediately met. involving positive reactivity additions that could result in loss of required SDM or boron concentration.

AND B.4 Initiate action to restore Immediately required DC electrical power subsystems to OPERABLE status.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.8.5-2 Unit 2 - Amendment No. 149

DC Sources-Shutdown 3.8.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.5.1 NOTE ----------------

The following SRs are not required to be performed: SR 3.8.4.2 and SR 3.8.4.3.

For DC sources required to be OPERABLE, the In accordance following SRs are applicable: with applicable SRs SR 3.8.4.1 SR 3.8.4.2 SR 3.8.4.3 Prairie Island Unit 1 -Amendment No. 158 Units 1 and 2 3.8.5-3 Unit 2 - Amendment No. 149

Battery Parameters 3.8.6 3.8 ELECTRICAL POWER SYSTEMS 3.8.6 Battery Parameters LCO 3.8.6 Battery parameters for Train A and Train B batteries shall be within limits.

APPLICABILITY: When associated DC electrical power subsystems are required to be OPERABLE.

ACTIONS

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

Separate Condition entry is allowed for each battery.

CONDITION REQUIRED ACTION COMPLETION TIME A. One battery with one or A.1 Perform SR 3.8.4.1. 8 hours0.333 days 0.0476 weeks 0.011 months more battery cells float voltage < 2.07 V. AND A.2 Perform SR 3.8.6.1. 8 hours0.333 days 0.0476 weeks 0.011 months AND A.3 Restores affected cell 24 hours1 days 0.143 weeks 0.0329 months voltage _>2.07 V.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.8.6-1 Unit 2 - Amendment No. 149

Battery Parameters 3.8.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One battery with float B.I Perform SR 3.8.4.1. 8 hours0.333 days 0.0476 weeks 0.011 months current > 2 amps.

AND B.2 Restore battery float 24 hours1 days 0.143 weeks 0.0329 months current to < 2 amps.

- NOTL -- ---- ----------------- NOTE---------

Required Action C.2 shall be Required Actions C. 1 and C.2 are completed if electrolyte level only applicable if electrolyte level was below the top of plates. was below the top of plates.

C. One battery with one or C. 1 Restore electrolyte level to 8 hours0.333 days 0.0476 weeks 0.011 months more cells electrolyte above top of plates.

level less than minimum established design limits. AND C.2 Verify no evidence of 12 hours0.5 days 0.0714 weeks 0.0164 months leakage.

AND C.3 Restore electrolyte level to 31 days greater than or equal to minimum established design limits.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.8.6-2 Unit 2 - Amendment No. 149

Battery Parameters 3.8.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. One battery with pilot D. I Restore battery pilot cell 12 hours0.5 days 0.0714 weeks 0.0164 months cell electrolyte temperature to >_ minimum temperature less than established design limits.

minimum established design limits.

E. Battery parameters in E.1 Restore battery parameters 8 hours0.333 days 0.0476 weeks 0.011 months both trains not within for battery in one train to limits, within limits.

F. Required Action and F. I Declare associated battery Immediately associated Completion inoperable.

Time of Condition A, B, C, D, or E not met.

OR One battery with one or more battery cells float voltage < 2.07 V and float current > 2 amps.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.8.6-3 Unit 2 - Amendment No. 149

Battery Parameters 3.8.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.1 --------------------------- NOTE --------------------------

Not required to be met when battery terminal voltage is less than the minimum established float voltage of SR 3.8.4.1.

Verify each battery float current is _<2 amps. 7 days SR 3.8.6.2 Verify each battery pilot cell voltage is >_ 2.07 V. 31 days SR 3.8.6.3 Verify each battery connected cell electrolyte level is 31 days greater than or equal to minimum established design limits.

SR 3.8.6.4 Verify each battery pilot cell temperature is greater 31 days than or equal to minimum established design limits.

SR 3.8.6.5 Verify each battery connected cell voltage 92 days is >_2.07 V.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.8.6-4 Unit 2 - Amendment No. 149

Battery Parameters 3.8.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.6.6 NOTE ---------------

This Surveillance shall not be performed in MODE 1, 2, 3, or 4. However, credit may be taken for unplanned events that satisfy this SR.

Verify battery capacity is 2!80% of the 60 months manufacturer's rating when subjected to a performance discharge test or a modified AND performance discharge test.

12 months when battery shows degradation, or has reached 85%

of the expected life with capacity

< 100% of manufacturer' s rating AND 24 months when battery has reached 85% of the expected life with capacity >

100% of manufacturer's rating L ______________________________________________________

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.8.6-5 Unit 2 - Amendment No. 149

Inverters-Operating 3.8.7 3.8 ELECTRICAL POWER SYSTEMS 3.8.7 Inverters-Operating LCO 3.8.7 Four Reactor Protection Instrument AC inverters shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One Reactor Protection A. 1 Verify Reactor Protection 2 hours0.0833 days 0.0119 weeks 0.00274 months Instrument AC inverter Instrument AC panel with inoperable, inoperable inverter is powered from Panel 117 (Unit 2 - Panel 217).

OR A.2 Verify Reactor Protection 2 hours0.0833 days 0.0119 weeks 0.00274 months Instrument AC panel with inoperable inverter is powered from its inverter bypass source.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.8.7-1 Unit 2 - Amendment No. 149

Inverters-Operating 3.8.7 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Two required Reactor ---- -------------- NOTE---------

Protection Instrument AC Enter applicable Conditions and inverters inoperable. Required Actions of LCO 3.8.9, "Distribution Systems-Operating" with any Reactor Protection Instrument AC panel de energized.

B.1 Verify no more than one 2 hours0.0833 days 0.0119 weeks 0.00274 months Reactor Protection Instrument AC panel is powered from Panel 117 (Unit 2 - Panel 217).

AND B.2 Verify one or both Reactor 2 hours0.0833 days 0.0119 weeks 0.00274 months Protection Instrument AC panel(s) is powered from an inverter bypass source.

AND B.3 Restore one inverter to 8 hours0.333 days 0.0476 weeks 0.011 months OPERABLE status.

C. Required Action and C.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND C.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.8.7-2 Unit 2 - Amendment No. 149

Inverters-Operating 3.8.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.7.1 Verify correct inverter voltage and alignment to 7 days required Reactor Protection Instrument AC panels.

Prairie Island Unit I Amendment No. 158 Units I and 2 3.8.7-3 Unit 2 Amendment No. 149

Inverters- Shutdown 3.8.8 3.8 ELECTRICAL POWER SYSTEMS 3.8.8 Inverters- Shutdown LCO 3.8.8 One Reactor Protection Instrument AC inverter shall be OPERABLE.

APPLICABILITY: MODES 5 and 6, During movement of irradiated fuel assemblies.

ACTIONS

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

LCO 3.0.3 not applicable.

S...........................................................................................................

CONDITION REQUIRED ACTION COMPLETION TIME A. One required inverter A.1 Suspend CORE Immediately inoperable. ALTERATIONS.

AND A.2 Suspend movement of Immediately irradiated fuel assemblies.

AND A.3 Suspend operations Immediately involving positive reactivity additions that could result in loss of required SDM or boron concentration.

AND Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.8.8-1 Unit 2 - Amendment No. 149

Inverters- Shutdown 3.8.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.4 Initiate action to restore Immediately required inverter to OPERABLE status.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.8.1 Verify correct inverter voltage and alignment to 7 days required Reactor Protection Instrument AC panel.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.8.8-2 Unit 2 - Amendment No. 149

Distribution Systems-Operating 3.8.9 3.8 ELECTRICAL POWER SYSTEMS 3.8.9 Distribution Systems-Operating LCO 3.8.9 Train A and Train B safeguards AC and DC, and Reactor Protection Instrument AC electrical power distribution subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more safeguards ------------- NOTE---------

AC electrical power Enter applicable Conditions and distribution subsystems Required Actions of LCO 3.8.4, inoperable. "DC Sources - Operating," for DC trains made inoperable by inoperable power distribution subsystems.

A. I Restore safeguards AC 8 hours0.333 days 0.0476 weeks 0.011 months electrical power distribution subsystems to AND OPERABLE status.

16 hours0.667 days 0.0952 weeks 0.0219 months from discovery of failure to meet LCO Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.8.9-1 Unit 2 - Amendment No. 149

Distribution Systems-Operating 3.8.9 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One or more safeguards B.1 Restore safeguards DC 2 hours0.0833 days 0.0119 weeks 0.00274 months DC electrical power electrical power distribution subsystems distribution subsystems to AND inoperable. OPERABLE status.

16 hours0.667 days 0.0952 weeks 0.0219 months from discovery of failure to meet LCO C. One Reactor Protection C. 1 Restore Reactor Protection 2 hours0.0833 days 0.0119 weeks 0.00274 months Instrument AC panel Instrument AC panel to inoperable. OPERABLE status. AND 16 hours0.667 days 0.0952 weeks 0.0219 months from discovery of failure to meet LCO D. Required Action and D.1 Be in MODE 3. 6 hours0.25 days 0.0357 weeks 0.00822 months associated Completion Time not met. AND D.2 Be in MODE 5. 36 hours1.5 days 0.214 weeks 0.0493 months Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.8.9-2 Unit 2 - Amendment No. 149

Distribution Systems-Operating 3.8.9 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. Two trains with E.l Enter LCO 3.0.3. Immediately inoperable distribution subsystems that result in a loss of safety function.

OR Two or more Reactor Protection Instrument AC panels inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.9.1 Verify correct breaker and switch alignments and 7 days voltage to safeguards AC, DC, and Reactor Protection Instrument AC electrical power distribution subsystems.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.8.9-3 Unit 2 - Amendment No. 149

Distribution Systems-Shutdown 3.8.10 3.8 ELECTRICAL POWER SYSTEMS 3.8.10 Distribution Systems-Shutdown LCO 3.8.10 The necessary portion of safeguards AC, DC, and Reactor Protection Instrument AC electrical power distribution subsystems shall be OPERABLE to support equipment required to be OPERABLE.

APPLICABILITY: MODES 5 and 6, During movement of irradiated fuel assemblies.

ACTIONS

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

LCO 3.0.3 is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.I Declare associated Immediately safeguards AC, DC, or supported required Reactor Protection feature(s) inoperable.

Instrument AC electrical power distribution OR subsystems inoperable.

A.2.1 Suspend CORE Immediately ALTERATIONS.

AND A.2.2 Suspend movement of Immediately irradiated fuel assemblies.

AND Prairie Island Unit I Amendment No. 158 Units 1 and 2 3.8.10-1 Unit 2 - Amendment No. 149

Distribution Systems-Shutdown 3.8.10 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.3 Suspend operations Immediately involving positive reactivity additions that could result in loss of required SDM or boron concentration.

AND A.2.4 Initiate actions to restore Immediately required safeguards AC, DC, and Reactor Protection Instrument AC electrical power distribution subsystems to OPERABLE status.

AND A.2.5 Declare associated Immediately required residual heat removal subsystem(s) inoperable and not in operation.

______________________________ .1__________________________________ L___________________

Prairie Island Unit 1 - Amendment No. 158 Units I and 2 3.8.10-2 Unit 2 - Amendment No. 149

Distribution Systems-Shutdown 3.8.10 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.10.1 Verify correct breaker and switch alignments and 7 days voltage to required safeguards AC, DC, and Reactor Protection Instrument AC electrical power distribution subsystems.

Prairie Island Unit 1 - Amendment No. 158 3.8.10-3 Unit 2 - Amendment No. 149 Units 1 and 2

Boron Concentration 3.9.1 3.9 REFUELING OPERATIONS 3.9.1 Boron Concentration LCO 3.9.1 Boron concentrations of the Reactor Coolant System and the refueling cavity shall be maintained within the limits specified in the COLR.

APPLICABILITY: MODE 6.

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

Only applicable to the refueling cavity when connected to the RCS.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Boron concentration A. I Suspend CORE Immediately not within limits. ALTERATIONS.

AND A.2 Suspend positive reactivity Immediately additions.

AND A.3 Initiate action to restore Immediately boron concentration to within limits.

Prairie Island Unit 1 - Amendment No. 158 Units I and 2 3.9.1-1 Unit 2 - Amendment No. 149

Boron Concentration 3.9.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.1.1 Verify boron concentration is within the limits 72 hours3 days 0.429 weeks 0.0986 months specified in COLR.

Prairie Island Unit 1 - Amendment No. 158 Units I and 2 3.9.1-2 Unit 2 - Amendment No. 149

Refueling Cavity Water Level 3.9.2 3.9 REFUELING OPERATIONS 3.9.2 Refueling Cavity Water Level LCO 3.9.2 Refueling cavity water level shall be maintained > 23 ft above the top of reactor vessel flange.

APPLICABILITY: During movement of irradiated fuel assemblies within containment.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Refueling cavity water A. 1 Suspend movement of Immediately level not within limit, irradiated fuel assemblies within containment.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.2.1 Verify refueling cavity water level is > 23 ft above 24 hours1 days 0.143 weeks 0.0329 months the top of reactor vessel flange.

Prairie Island Unit I - Amendment No. 158 Units I and 2 3.9.2-1 Unit 2 - Amendment No. 149

Nuclear Instrumentation 3.9.3 3.9 REFUELING OPERATIONS 3.9.3 Nuclear Instrumentation LCO 3.9.3 Two core subcritical neutron flux monitors shall be OPERABLE.

AND One core subcritical neutron flux monitor audible count rate circuit shall be OPERABLE.

APPLICABILITY: MODE 6.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required core A. 1 Suspend CORE Immediately subcritical neutron flux ALTERATIONS.

monitor inoperable.

AND A.2 Suspend operations that Immediately would cause introduction into the RCS, coolant with boron concentration less than required to meet the boron concentration of LCO 3.9.1.

Prairie Island Unit 1 - Amendment No. 158 Units I and 2 3.9.3-1 Unit 2 - Amendment No. 149

Nuclear Instrumentation 3.9.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Two required core B.1 Initiate action to restore Immediately subcritical neutron flux one core subcritical monitors inoperable, neutron flux monitor to OPERABLE status.

AND B.2 Perform SR 3.9.1.1. Once per 12 hours0.5 days 0.0714 weeks 0.0164 months C. Required core subcritical C. 1 Initiate action to isolate Immediately neutron flux monitor unborated water sources.

audible count rate circuit inoperable. AND C.2 Suspend CORE Immediately ALTERATIONS.

Prairie Island Unit I - Amendment No. 158 Units I and 2 3.9.3-2 Unit 2 - Amendment No. 149

Nuclear Instrumentation 3.9.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.3.1 Perform CHANNEL CHECK. 12 hours0.5 days 0.0714 weeks 0.0164 months SR 3.9.3.2 ------------------ NOTE ---------------

Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION. 24 months Prairie Island Unit 1 -Amendment No. 158 Units 1 and 2 3.9.3-3 Unit 2 - Amendment No. 149

Containment Penetrations 3.9.4 3.9 REFUELING OPERATIONS 3.9.4 Containment Penetrations LCO 3.9.4 The containment penetrations shall be in the following status:

a. The equipment hatch closed and held in place by four bolts;

b. One door in each air lock closed, or both doors in each air lock may be open with:

1. containment (high flow) purge system isolated,

2. one air lock door OPERABLE, and

3. at least two containment fan coil unit fans capable of operating in the high speed mode; and

c. Each penetration providing direct access from the containment atmosphere to the outside atmosphere either:

1. closed by a manual or automatic isolation valve, blind flange, or equivalent, or

2. capable of being closed by an OPERABLE Containment Ventilation Isolation System.

-NOTE Penetration flow path(s) providing access from the containment atmosphere to the outside atmosphere may be unisolated under administrative controls.

APPLICABILITY: During movement of irradiated fuel assemblies within containment.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.9.4-1 Unit 2 - Amendment No. 149

Containment Penetrations 3.9.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more containment A. 1 Suspend movement of Immediately penetrations not in irradiated fuel assemblies required status, within containment.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.4.1 Verify each required containment penetration is in 7 days the required status.

SR 3.9.4.2 ------------------ NOTE ---------------

Not required to be met for containment purge (high flow) and inservice (low flow) purge valve(s) in penetrations closed to comply with LCO 3.9.4.c. 1.

Verify each required containment purge (high flow) 24 months and inservice (low flow) purge system valve actuates to the isolation position on an actual or simulated actuation signal.

Prairie Island Unit 1 -Amendment No. 158 Units 1 and 2 3.9.4-2 Unit 2 - Amendment No. 149

RHR and Coolant Circulation-High Water Level 3.9.5 3.9 REFUELING OPERATIONS 3.9.5 Residual Heat Removal (RHR) and Coolant Circulation-High Water Level LCO 3.9.5 One RHR loop shall be OPERABLE and in operation.

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

The required RHR loop may be removed from operation 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 no operations are permitted that would cause introduction into the Reactor Coolant System, coolant with boron concentration less than that required to meet the minimum required boron concentration of LCO 3.9.1.

APPLICABILITY: MODE 6 with the water level >_20 ft above the top of reactor vessel flange.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RHR loop requirements A. 1 Suspend operations that Immediately not met. would cause introduction into the RCS, coolant with boron concentration less than required to meet the boron concentration of LCO 3.9.1.

AND A.2 Suspend loading irradiated Immediately fuel assemblies in the core.

AND Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.9.5-1 Unit 2 - Amendment No. 149

RHR and Coolant Circulation-High Water Level 3.9.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.3 Initiate action to satisfy Immediately RHR loop requirements.

AND A.4 Close equipment hatch and 4 hours0.167 days 0.0238 weeks 0.00548 months secure with four bolts.

AND A.5 Close one door in each 4 hours0.167 days 0.0238 weeks 0.00548 months airlock.

AND A.6.1 Close each penetration 4 hours0.167 days 0.0238 weeks 0.00548 months providing direct access from the containment atmosphere to the outside atmosphere with a manual or automatic isolation valve, or blind flange.

OR A.6.2 Verify each penetration is 4 hours0.167 days 0.0238 weeks 0.00548 months capable of being closed by an OPERABLE Containment Ventilation Isolation System.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.9.5-2 Unit 2 - Amendment No. 149

RHR and Coolant Circulation-High Water Level 3.9.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.5.1 Verify one RHR loop is in operation. 12 hours0.5 days 0.0714 weeks 0.0164 months Prairie Island Unit 1 - Amendment No. 158 Units I and 2 3.9.5-3 Unit 2 - Amendment No. 149

RHR and Coolant Circulation-Low Water Level 3.9.6 3.9 REFUELING OPERATIONS 3.9.6 Residual Heat Removal (RHR) and Coolant Circulation-Low Water Level Two RHR loops shall be OPERABLE, and one RHR loop shall be in LCO 3.9.6 operation.

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

1. Both 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. The core outlet temperature is maintained > 10 degrees F below saturation temperature;

b. No operations are permitted that would cause a reduction of the Reactor Coolant System (RCS) boron concentration; and

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

2. One required RHR loop may be inoperable for up to 2 hours0.0833 days 0.0119 weeks 0.00274 months for surveillance testing, provided that the other RHR loop is OPERABLE and in operation.

APPLICABIIfTY: MODE 6 with the water level < 20 ft above the top of reactor vessel flange.

Unit 1 - Amendment No. 158 Prairie Island 3.9.6-1 Unit 2 - Amendment No. 149 Units 1 and 2

RHR and Coolant Circulation-Low Water Level 3.9.6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Less than the required A. I Initiate action to restore Immediately number of RHR loops required RHR loop(s) to OPERABLE. OPERABLE status.

OR A.2 Initiate action to establish Immediately

> 20 ft of water above the top of reactor vessel flange.

B. No RHR loop in B. 1 Suspend operations that Immediately operation. would cause introduction into the RCS, coolant with boron concentration less than required to meet the boron concentration of LCO 3.9.1.

AND B.2 Initiate action to restore one Immediately RHR loop to operation.

AND B.3 Close equipment hatch and 4 hours0.167 days 0.0238 weeks 0.00548 months secure with four bolts.

AND B.4 Close one door in each air 4 hours0.167 days 0.0238 weeks 0.00548 months lock.

AND Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.9.6-2 Unit 2 - Amendment No. 149

RHR and Coolant Circulation-Low Water Level 3.9.6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.5.1 Close each penetration 4 hours0.167 days 0.0238 weeks 0.00548 months providing direct access from the containment atmosphere to the outside atmosphere with a manual or automatic isolation valve, or blind flange.

OR B.5.2 Verify each penetration is 4 hours0.167 days 0.0238 weeks 0.00548 months capable of being closed by an OPERABLE Containment Ventilation Isolation System.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.6.1 Verify one RHR loop is in operation. 12 hours0.5 days 0.0714 weeks 0.0164 months SR 3.9.6.2 Verify correct breaker alignment and indicated power 7 days available to the required RHR pump that is not in operation.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 3.9.6-3 Unit 2 - Amendment No. 149

Design Features 4.0 4.0 DESIGN FEATURES 4.1 Site Location The site for the Prairie Island Nuclear Generating Plant is located on the west bank of the Mississippi River, approximately 6 miles northwest of the city of Red Wing, Minnesota. The site exclusion area boundary has a minimum radius of 715 meters from the center line of either reactor.

4.2 Reactor Core 4.2.1 Fuel Assemblies The reactor shall contain 121 fuel assemblies. Each assembly shall consist of a matrix of Zircaloy or ZIRLO fuel rods with an initial composition of natural or slightly enriched uranium dioxide (U0 2) as fuel material.

Limited substitutions of zirconium alloy or stainless steel filler rods for fuel rods, in accordance with approved applications of fuel rod configurations, may be used. Fuel assemblies shall be limited to those fuel designs that have been analyzed with applicable NRC staff approved codes and methods and shown by tests or analyses to comply with all fuel safety design bases.

A limited number of lead test assemblies that have not completed representative testing may be placed in nonlimiting core regions.

4.2.2 Control Rod Assemblies The reactor core shall contain 29 control rod assemblies. The control material shall be silver indium cadmium as approved by the NRC.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 4.0-1 Unit 2 - Amendment No. 149

Design Features 4.0 4.0 DESIGN FEATURES (continued) 4.3 Fuel Storage 4.3.1 Criticality 4.3.1.1 The spent fuel storage racks are designed and shall be maintained with:

a. Fuel assemblies having a maximum U-235 enrichment of 5.0 weight percent;

b. keff < 1.0 if fully flooded with unborated water, which includes an allowance for uncertainties as described in Reference 1;

c. keff !<0.95 if fully flooded with water borated to 750 ppm, which includes an allowance for uncertainties as described in Reference 1;

d. A nominal 9.5 inch center to center distance between fuel assemblies placed in the fuel storage racks;

e. New or spent fuel assemblies with a combination of discharge burnup, initial enrichment and decay time in the "unrestricted range" of Figure 3.7.17-1 or Figure 3.7.17-2, as applicable, may be allowed unrestricted storage in the fuel storage racks; and

f. New or spent fuel assemblies with a combination of discharge burnup, initial enrichment and decay time in the "restricted range" of Figure 3.7.17-1 or Figure 3.7.17-2, as applicable, will be stored in compliance with Figures 4.3.1-1 through 4.3.1-12.

Prairie Island Unit 1 - Amendment No. 158 Units l and 2 4.0-2 Unit 2 - Amendment No. 149

Design Features 4.0 4.0 DESIGN FEATURES 4.3 Fuel Storage (continued) 4.3.1.2 The new fuel storage racks are designed and shall be maintained with:

a. Fuel assemblies having a maximum U-235 enrichment of 5.0 weight percent;

b. kff -<0.95 if fully flooded with unborated water, which includes an allowance for uncertainties as described in Reference 2;

c. k~ff *< 0.98 if accidentally filled with a low density moderator which resulted in optimum low density moderation conditions; and

d. A nominal 21 inch center to center distance between fuel assemblies placed in the storage racks.

4.3.1.3 Fuel will not be inserted into a TN-40 spent fuel cask in the pool unless a minimum boron concentration of 1800 ppm is present.

The 1800 ppm will ensure that keff for the spent fuel cask, including statistical uncertainties, will be _<0.95 for all postulated arrangements of fuel within the cask. The criticality analyses for the TN-40 spent fuel storage cask were based on fresh fuel enriched to 3.85 weight percent U-235.

4.3.2 Drainage The spent fuel storage pool is designed and shall be maintained to prevent inadvertent draining of the pool below elevation 727' 4" (Mean Sea Level).

Prairie Island Unit 1 - Amendment No. 158 Units l and 2 4.0-3 Unit 2 - Amendment No. 149

Design Features 4.0 4.0 DESIGN FEATURES 4.3 Fuel Storage (continued) 4.3.3 Capacity The spent fuel storage pool is designed and shall be maintained with a storage capacity limited to no more than 1386 fuel assemblies not including those assemblies which can be returned to the reactor. The southeast corner of the small pool serves as the spent fuel cask lay down area. To facilitate plant evolutions, four additional storage racks, with a combined capacity of 196, may be temporarily installed in the cask lay down area to provide a total of 1582 storage locations (Ref. 3).

REFERENCES 1. "Northern States Power Prairie Island Units 1 and 2 Spent Fuel Rack Criticality Analysis Using Soluble Boron Credit",

Westinghouse Commercial Nuclear Fuel Division, February 1997.

2. "Criticality Analysis of the Prairie Island Units 1 & 2 Fresh and Spent Fuel Racks", Westinghouse Commercial Nuclear Fuel Division, February 1993.

3. USAR, Section 10.2.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 4.0-4 Unit 2 - Amendment No. 149

Dcsign Featurcs 4.0

Fresh Fuel: Must be less than or equal to Nominal 4.95 w/o ---U No restrictions on burnup Burned Fuel: Must satisfy minimum burnup requirements of Figures 4.3.1-3 through 4.3.1-12 depending on number of GAD rods in fresh fuel FIGURE 4.3.1-1 Spent Fuel Pool Burned/Fresh Checkerboard Cell Layout Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 4.0-5 Unit 2 - Amendment No. 149

Design Features 4.0 Interface Fresh Fuel: Must be less than or equal to nominal 4.95 w/o 235U No restrictions on burnup Burned Fuel: 3x3 Checkerboard Region Must satisfy minimum bumup requirements of Figures 4.3.1-3 through 4.3.1-12 Burned Fuel: All Cell Unrestricted Region Must satisfy minimum burnup requirements of Figures 3.7.17-1 or 3.7.17-2 FIGURE 4.3.1-2 Spent Fuel Pool Checkerboard Interface Requirements Prairie Island Unit 1 - Amendment No. 158 Units I and 2 4.0-6 Unit 2 - Amendment No. 149

Design Feature 4.0 5500' 0 0 Years 5000 0 5 Years 10 Years "o/

15 Years 4500 20 Years ACCEPTABLE -o4-ti1-4000 -t I1,' -

S10, 0 '0 /,

I "r.,

i 3500 czzi~zzi~I1zf1 04 co 3000

>1 C-------------------

2500 J

fl nl n n,.-- -- .I--+~L'- - 4 - -

NNNA rz4 0- 1 1- - - - I I 1500( I- Y- - - - I1 I

--- - I - NOT ACCEPTABLE 1000 500 0 0 1

1- -- -- -- --

1.0 2.0 3.0 4.0 5 .0 Initial U-235 Enrichment (w/o)

FIGURE 4.3.1-3 Spent Fuel Pool Checkerboard Region Burnup and Decay Time Requirements - OFA Fuel, No GAD Prairie Island Unit I- Amendment No. 158 Units 1 and 2 4.0-7 Unit 2 - Amendment No. 149

Design Feature 4.0 6000C 0 Years

- ,.- .- I .- -

Of[/ 5 Years 10 Years 50000 15 Years ACCEPTABLE " / 20 Years E-4

",/I//*

40000

/ / /',1 A/Z//;

>1 V/0 2 30000 U) o' wl

/ y//,'

2o0o00 NOT ACCEPTABLE 10000 ,,

(

1.0 2.0 3.0 4.0 5.0 Initial U-235 Enrichment (w/o)

FIGURE 4.3.1-4 Spent Fuel Pool Checkerboard Region Burnup and Decay Time Requirements - STD Fuel, No GAD Prairie Island Unit 1 - Amendment No. 158 Units I and 2 4.0-8 Unit 2 - Amendment No. 149

Design Feature 4.0 6000 0 1 i

________ I I I 5000 ACCEPTABLE H 1 f ,

t--I 0 Years PFi 5 Years 10 Years 15 Years 20 Years 4000 04

>1 3000 1!1 IV, -IZ/ Ii U) f.0 tO 5-4 2000 NOT ACCEPTABLE 0z e 1000 0~1

/..- ----

1.0 2.0 3.0 4.0 5.0 Initial U-235 Enrichment (w/o)

FIGURE 4.3.1-5 Spent Fuel Pool Checkerboard Region Burnup and Decay Time Requirements - OFA Fuel, 4 GAD Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 4.0-9 Unit 2 - Amendment No. 149

Design Feature 4.0 60000

___ I I!_ I/ o Years 50000 IACCEPTABLE I 1 vi*/

, 5 Years ii I!i -,111K i- 10 Years 15 Years 20 Years E40000 II VVY%

/ vvlýý r30000 i NOT ACCEPTABLE 10000 I JYL 1 .0 2.0 3.0 4.0 5 .0 Initial U-235 Enrichment (w/o)

FIGURE 4.3..1-6 Spent Fuel Pool Checkerboard Region Burnup and Decay Time Requirements - STD Fuel, 4 GAD Prairie Island Unit 1 - Amendment No. 158 Units I and 2 4.0-10 Unit 2 - Amendment No. 149

Design Feature 4.0 5000 ~0

___ _____ I Ii IZ I I I 4500 0 I i I I ___ __ I I i I ACCEPTABLE i =i J I 0 Years

j 4000 C- -i- 5 Years IIFFl J K II /

10 Years 15 Years 20 Years

/ I/ v '1e S3500 0- AI iiiiI !I I__/_

S3000 l ! ! i---I.'/

S2500 0ozz~zzzz - )II/./ v E

a)

V2

< 2000 --.- ////I j-- i I /I/7/i__

1500 1000 ~- --- - -

!/~*I NOT ACCEPTABLE ii I t 500 oi -1 1 L.0 2.0 3.0 4.0 5.0 Initial U-235 Enrichment (w/o)

FIGURE 4.3.1 -7 Spent Fuel Pool Checkerboard Region Burnup and Decay Time Requirements - OFA Fuel, 8 GAD Prairie Island Unit I -Amendment No. 158 Units 1 and 2 4.0-11 Unit 2 - Amendment No. 149

Design Feature 4.0 50000i- I I I I I tI ! i i i i i i II II i I ! I

__ __ __ i i t 5zthi I I I 0 Years 4500 )0I i zLL -H 111 ______ -[

__---ii 5 Years i1..L11 I i 10 Years ACCEPTABLE ---

LII ______/_,__"/

- / 15 Years 4000 20 Years i f , ! !

I

/ !.(

! II

/ t/_/_/!

S3500 I 7___

t - i/ _

I A/// /

C T"T/

S3000 0 1 v xI I I 1 141 I 1/I /Y"t S2500 0 I i , i r A tV/iX J _q f/y/

1 i1- I I_

U) 0 /Z

< 2000 t- iI i!//!~i 1500 S,-NOT ACCEPTABLE 1000 0/1

+/-M

_ I ' ~'~ zizlz i It 500(

0,n

//

1.0 2.0 3.0 4.0 5.0 Initial U-235 Enrichment (w/o)

FIGURE 4.3.1-8 Spent Fuel Pool Checkerboard Region Burnup and Decay Time Requirements - STD Fuel, 8 GAD Prairie Island Unit 1 - Amendment No. 158 Units I and 2 4.0-12 Unit 2 - Amendment No. 149

Design Feature 4.0 45000 I I I4..JA]I . ____

4000C 11 0 Years I 7-

___ __ I

_t i_ _____/ I 5 Years 10 Years 4.,.

ACCEPTABLEI 15 Years 350C 1 I i . , l /f/ i/

20 Years 11II ZtII!ZI I i//{/

f F x 3000

- -~ Ii Ii /tll --

z 0 I 1 ////)ii I ,/ / 11/

2500

>1 I I /Z 1////

~~z~iz S, i 111t i2 t 1 w 2000 o1 i i - /7/t i it 0)

1500 1000 o - I--I--. /i,

-- NOT ACCEPTABLE' _!_

_" _ I 5oo 0 -i 1.0 2.0 3.0 4.0 5.0 Initial U-235 Enrichment (w/o)

FIGURE 4.3.1-9 Spent Fuel Pool Checkerboard Region Burnup and Decay Time Requirements - OFA Fuel, 12 GAD Prairie Island Unit 1 -Amendment No. 158 Units 1 and 2 4.0-13 Unit 2 - Amendment No. 149

Design Features 4.0 4500' 0 Years

° 'i ' ,_ _'

iI 1 1 1i 1 7 o IIII~III ! , I , 5 Years 4000( 20 Years Years 20 Years

- ACCEPTABLE i /

3500( SA'///i S I~

-/- - !___,

III iIl,'A!Y-i 3000C FEE i ,_

2500( 0 I/

/

I/ 'J/AIA if

>4 in [] l I /-M / !/ Ij/l ltx I I 2000C r4 0w A Vi- t 15000 /A'/

oi~

OF NOT ACCEPTABLE 10000 11111 AI 0 I

- t]

1.0 2.0 3.0 4.0 5.0 Initial U-235 Enrichment (w/o)

FIGURE 4.3.1-10 Spent Fuel Pool Checkerboard Region Burnup and Decay Time Requirements - STD Fuel, 12 GAD Prairie Island Unit 1 - Amendment No. 158 Units I and 2 4.0-14 Unit 2 - Amendment No. 149

Design Feature 4.0 45000 I i I I I I I . I I I k I . I i I I__

________ 7 F

~1 i1 I !__

4000 0 - I, Ii 0 Years 5 Years ACCEPTABLE 10 Years 3500 )0 15 Years 20 Years IIIII/ I Z/

3000 )0i

/

! - - - ! - - - M - ! i 9 - i

!/ y///

iz~v1---- -- ~ll" S2500 AII w2000 0t 1-- ~Fji---I U2 F<

S1500

-- - -- & -I NOT ACCEPTABLE 1000 A - II 500 01 117 1.0 2.0 3.0 4.0 5.0 Initial U-235 Enrichment (w/o)

FIGURE 4.3.1-11 Spent Fuel Pool Checkerboard Region Burnup and Decay Time Requirements - OFA Fuel, 16 or More GAD Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 4.0-15 Unit 2 - Amendment No. 149

Design Feature 4.0 I

I 45000 I

O Years 40000 iL 5 Years

- . Iii ACCEPTABLE II 111 1L1 / I/Vy 10 Years 15 Years 20 Years

/ / /V1/

35000 I/

I !~ I ~

i!

, iiA 4L i/f 41111 30000 . ý I . , . I I ý ý I I / I/ Y/Y

.4 y l/y I/ 1 I-I /Z IL 25000 /Z/Il

'I E

>1 a)

- - K I !_I_

I

//

II"/i//t 20000 r14 TI I I I

,--4 15000 ii 1.1//I I ~

- -- -- I

!I//-I -NOT ACCEPTABLE 10000 Aj 5000

/

0

1. 0 2.0 3.0 4.0 5.0 Initial U-235 Enrichment (w/o)

FIGURE 4.3.1-12 Spent Fuel Pool Checkerboard Region Burnup and Decay Time Requirements - STD Fuel, 16 or More GAD Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 4.0-16 Unit 2 - Amendment No. 149

Responsibility 5.1 5.0 ADMINISTRATIVE CONTROLS 5.1 Responsibility 5.1.1 The plant manager shall be responsible for overall unit operation and shall delegate in writing the succession to this responsibility during his absence.

The plant manager or his designee shall approve, prior to implementation, each proposed test, experiment or modification to systems or equipment that affect nuclear safety.

5.1.2 The shift supervisor (SS) shall be responsible for the control room command function. During any absence of the SS from the control room while the unit is in MODE 1, 2, 3, or 4, an individual with an active senior reactor operator (SRO) license shall be designated to assume the control room command function. During any absence of the SS from the control room while the unit is in MODE 5 or 6, an individual with an active SRO license or reactor operator (RO) license shall be designated to assume the control room command function.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 5.0-1 Unit 2 - Amendment No. 149

Organization 5.2 5.0 ADMINISTRATIVE CONTROLS 5.2 Organization 5.2.1 Onsite and Offsite Organizations Onsite and offsite organizations shall be established for plant operation and corporate management, respectively. The onsite and offsite organizations shall include the positions for activities affecting safety of the nuclear power plant.

a. Lines of authority, responsibility, and communication shall be defined and established throughout highest management levels, intermediate levels, and all operating organization positions. These relationships shall be documented and updated, as appropriate, in organization charts, functional descriptions of departmental responsibilities and relationships, and job descriptions for key personnel positions, or in equivalent forms of documentation. These requirements, including the plant specific titles of those personnel fulfilling the responsibilities of the positions delineated in these Technical Specifications, shall be documented in the Updated Safety Analysis Report (USAR);

b. The plant manager shall be responsible for overall safe operation of the plant and shall have control over those onsite activities necessary for safe operation and maintenance of the plant;

c. A corporate officer shall have corporate responsibility for overall plant nuclear safety and shall take any measures needed to ensure acceptable performance of the staff in operating, maintaining, and providing technical support to the plant to ensure nuclear safety; and

d. The individuals who train the operating staff, carry out health physics, or perform quality assurance functions may report to the appropriate onsite manager; however, these individuals shall have sufficient organizational freedom to ensure their independence from operating pressures.

Prairie Island Unit 1 -Amendment No. 158 Units I and 2 5.0-2 Unit 2 - Amendment No. 149

Organization 5.2 5.2 Organization (continued) 5.2.2 Plant Staff The plant staff organization shall include the following:

a. An operator to perform non-licensed duties shall be assigned to each reactor containing fuel and one additional operator to perform non licensed duties shall be assigned when either or both reactors are operating in MODES 1, 2, 3, or 4.

b. Shift crew composition may be less than the minimum requirement of 10 CFR 50.54(m)(2)(i) and 5.2.2.a and 5.2.2.f for a period of time not to exceed 2 hours0.0833 days 0.0119 weeks 0.00274 months in order to accommodate unexpected absence of on duty shift crew members provided immediate action is taken to restore the shift crew composition to within the minimum requirements.

c. An individual qualified in radiation protection procedures shall be on site when fuel is in a reactor. The position may be vacant for not more than 2 hours0.0833 days 0.0119 weeks 0.00274 months , in order to provide for unexpected absence, provided immediate action is taken to fill the required position.

d. Administrative procedures shall be developed and implemented to limit the working hours of personnel who perform safety related functions (e.g., licensed SROs, licensed ROs, health physicists, auxiliary operators, and key maintenance personnel).

The procedures shall include guidelines on working hours that ensure adequate shift coverage shall be maintained without routine heavy use of overtime.

Any deviation from the working hour guidelines shall be authorized in advance by the plant manager or designee, in accordance with approved administrative procedures and with documentation of the basis for granting the deviation.

Controls shall be included in the procedures to require a periodic independent review be conducted to ensure that excessive hours Prairie Island Unit 1- Amendment No. 158 Units l and 2 5.0-3 Unit 2 - Amendment No. 149

Organization 5.2 5.2 Organization 5.2.2 Plant Staff (continued) have not been assigned. Routine deviation from the working hour guidelines shall not be authorized.

e. The operations manager or assistant operations manager shall hold an SRO license. In addition, the duty shift manager shall hold an SRO license.

f. In MODES 1, 2, 3, and 4, the shift technical advisor shall provide advisory technical support to the unit operations shift crew in the areas of thermal hydraulics, reactor engineering, and plant analysis with regard to the safe operation of the unit.

Prairie Island Unit 1 -Amendment No. 158 Units 1 and 2 5.0-4 Unit 2 - Amendment No. 149

Plant Staff Qualifications 5.3 5.0 ADMINISTRATIVE CONTROLS 5.3 Plant Staff Qualifications 5.3.1 Each member of the plant staff shall meet or exceed the minimum qualifications of Regulatory Guide 1.8, Revision 1, September 1975 except for (1) personnel who perform the function of shift technical advisor shall hold an SRO license and have a bachelors degree or equivalent in a scientific or engineering discipline with specific training in plant design, and response and analysis of the plant for transients and accidents, and (2) the operations manager who shall meet the requirements of ANSI N 18.1 1971, except that NRC license requirements are as specified in TS 5.2.2.e.

5.3.2 For the purpose of 10 CFR 55.4, a licensed senior reactor operator (SRO) and a licensed reactor operator (RO) are those individuals who, in addition to meeting the requirements of TS 5.3.1, perform the functions described in 10 CFR 50.54(m).

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 5.0-5 Unit 2 - Amendment No. 149

Procedures 5.4 5.0 ADMINISTRATIVE CONTROLS 5.4 Procedures 5.4.1 Written procedures shall be established, implemented, and maintained covering the following activities:

a. The applicable procedures recommended in Regulatory Guide 1.33, Revision 2, Appendix A, February 1978;

b. The emergency operating procedures required to implement the requirements of NUREG-0737 and NUREG-0737, Supplement 1, as stated in Generic Letter 82-33;

c. Quality control for effluent and environmental monitoring;

d. Fire Protection Program implementation; and

e. All programs specified in Specification 5.5.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 5.0-6 Unit 2 - Amendment No. 149

Programs and Manuals 5.5 5.0 ADMINISTRATIVE CONTROLS 5.5 Programs and Manuals The following programs shall be established, implemented, and maintained.

5.5.1 Offsite Dose Calculation Manual (ODCM)

a. The ODCM shall contain the methodology and parameters used in the calculation of offsite doses resulting from radioactive gaseous and liquid effluents, in the calculation of gaseous and liquid effluent monitoring alarm and trip setpoints, and in the conduct of the radiological environmental monitoring program; and

b. The ODCM shall also contain the radioactive effluent controls and radiological environmental monitoring activities, and descriptions of the information that should be included in the Annual Radiological Environmental Monitoring, and Radioactive Effluent Reports required by Specification 5.6.2 and Specification 5.6.3.

Changes to the ODCM:

a. Shall be documented and records of reviews performed shall be retained. This documentation shall contain:

1. sufficient information to support the change(s) together with the appropriate analyses or evaluations justifying the change(s), and

2. a determination that the change(s) maintain the levels of radioactive effluent control required by 10 CFR 20.1302, 40 CFR 190, 10 CFR 50.36a, and 10 CFR 50, Appendix I, and not adversely impact the accuracy or reliability of effluent, dose, or setpoint calculations;

b. Shall become effective after the approval by a member of plant management designated by the plant manager; and Prairie Island Unit 1 - Amendment No. 158 Units l and 2 5.0-7 Unit 2 - Amendment No. 149

Progranis and Manuals 5.5 5.5 Programs and Manuals 5.5.1 Offsite Dose Calculation Manual (ODCM) (continued)

c. Shall be submitted to the NRC in the form of a complete, legible copy of the entire ODCM as a part of or concurrent with the Radioactive Effluent Report for the period of the report in which any change in the ODCM was made. Each change shall be identified by markings in the margin of the affected pages, clearly indicating the area of the page that was changed. The date (i.e., month and year) the change was implemented shall be indicated.

5.5.2 Primary Coolant Sources Outside Containment This program provides controls to minimize leakage from those portions of systems outside containment that could contain highly radioactive fluids during a serious transient or accident to levels as low as practical. The systems include portions of the Residual Heat Removal and Safety Injection Systems. The program shall include the following:

a. Preventive maintenance and periodic visual inspection requirements; and

b. Integrated leak test requirements for each system at refueling cycle intervals or less.

5.5.3 Post Accident Sampling This program provides controls that ensure the capability to obtain and analyze reactor coolant, radioactive gases, and particulates in plant gaseous effluents and containment atmosphere samples under accident conditions.

The program shall include the following:

a. Training of personnel;

b. Procedures for sampling and analysis; and

c. Provisions for maintenance of sampling and analysis equipment.

Prairie Island Unit 1 - Amendment No. 158 Units I and 2 5.0-8 Unit 2 - Amendment No. 149

Programs and Mianuals 5.5 5.5 Programs and Manuals (continued) 5.5.4 Radioactive Effluent Controls Program This program conforms to 10 CFR 50.36a for the control of radioactive effluents and for maintaining the doses to members of the public from radioactive effluents as low as reasonably achievable.

This program shall allocate releases equally to each unit. The liquid radwaste treatment system, waste gas treatment system, containment purge release vent, and spent fuel pool vent are shared by both units. Experience has also shown that contributions from both units are released from each auxiliary building vent. Therefore, all releases will be allocated equally in determining conformance to the design objectives of 10 CFR 50, Appendix I.

The program shall be contained in the ODCM. shall be implemented by procedures, and shall include remedial actions to be taken whenever the program limits are exceeded. The program shall include the following elements:

a. Limitations on the functional capability of radioactive liquid and gaseous monitoring instrumentation including surveillance tests and setpoint determination in accordance with the methodology in the ODCM;

b. Limitations on the concentrations of radioactive material released in liquid effluents to unrestricted areas, conforming to ten times the concentration values in Appendix B, Table 2, Column 2 to 10 CFR 20.1001-20.2402;

c. Monitoring, sampling, and analysis of radioactive liquid and gaseous effluents in accordance with 10 CFR 20.1302 and with the methodology and parameters in the ODCM;

d. Limitations on the annual and quarterly doses or dose commitment to a member of the public from radioactive materials in liquid effluents released from each unit to unrestricted areas, conforming to 10 CFR 50, Appendix I; Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 5.0-9 Unit 2 - Amendment No. 149

Programs and Manuals 5.5 Programs and Manuals 5.5.4 Radioactive Effluent Controls Program (continued)

e. Determination of cumulative dose contributions from radioactive effluents for the current calendar quarter and current calendar year in accordance with the methodology and parameters in the ODCM.

Determination of projected dose contributions for radioactive effluents in accordance with the methodology in the ODCM at least every 31 days;

f. Limitations on the functional capability and use of the liquid and gaseous effluent treatment systems to ensure that appropriate portions of these systems are used to reduce releases of radioactivity when the projected doses in a period of 31 days from the liquid effluent releases would exceed 0.12 mrem to the total body or 0.4 mrem to any organ; or from the gaseous effluent releases would exceed 0.4 mrad for gamma air dose, 0.8 mrad for beta air dose, or 0.6 mrem organ dose;

g. Limitations on the dose rate resulting from radioactive material released in gaseous effluents from the site to areas at or beyond the site boundary shall be in accordance with the following:

1. for noble gases: a dose rate _<500 mrem/yr to the whole body and a dose rate _*3000 mrem/yr to the skin, and

2. for iodine- 131, iodine- 133, tritium, and all radionuclides in particulate form with half-lives greater than 8 days: a dose rate

< 1500 mrem/yr to any organ;

h. Limitations on the annual and quarterly air doses resulting from noble gases released in gaseous effluents from each unit to areas beyond the site boundary, conforming to 10 CFR 50, Appendix 1;

i. Limitations on the annual and quarterly doses to a member of the public from iodine-131, iodine-133, tritium, and all radionuclides in particulate form with half-lives > 8 days in gaseous effluents released from each unit to areas beyond the site boundary, conforming to 10 CFR 50, Appendix I; and Prairie Island Unit I - Amendment No. 158 Units 1 and 2 5.0-10 Unit 2 - Amendment No. 149

l1rouratis and NMInuals 5~.5 Programs and Manuals 5.5.4 Radioactive Effluent Controls Program (continued)

j. Limitations on the annual dose or dose commitment to any member of the public, beyond the site boundary, due to releases of radioactivity and to radiation from uranium fuel cycle sources, conforming to 40 CFR 190.

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Radioactive Effluent Controls Program surveillance frequency.

5.5.5 Comnonent Cvclic or Transient Limit This program provides controls to track the USAR, Section 4.1.4, cyclic and transient occurrences to ensure that components are maintained within the design limits.

5.5.6 Reactor Coolant Pump) Flwvheel Inspection Program This program shall provide for the inspection of each reactor coolant pump flywheel per the recommendations of Regulatory Position C.4.b of Regulatory Guide 1.14, Revision 1, August 1975. In lieu of Position C.4.b(l) and C.4.b(2), a qualified in-place UT examination over the volume from the inner bore of the flywheel to the circle one-half of the outer radius or a surface examination (MT or PT) of exposed surfaces of the removed flywheels may be conducted at approximately 10 year intervals coinciding with the Inservice Inspection schedule as required by ASME Section XI.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 5.0-11 Unit 2 - Amendment No. 149

Irogranis and Manual s 5:.5 5.5 Programs and Manuals (continued) 5.5.7 Inservice Testing Program This program provides controls for inservice testing of ASME Code Class 1,2, and 3 components. The program shall include the following:

a. Testing frequencies specified in Section XI of the ASME Boiler and Pressure Vessel Code and applicable Addenda as follows:

ASME Boiler and Pressure Vessel Code and applicable Addenda terminology for Required Frequencies inservice testing for performing inservice activities testing activities Weekly At least once per 7 days Monthly At least once per 31 days Semiquarterly At least once per 46 days Quarterly or every 3 months At least once per 92 days Semiannually or every 6 months At least once per 184 days Every 9 months At least once per 276 days Yearly or annually At least once per 366 days Biennially or every 2 years At least once per 731 days

b. The provisions of SR 3.0.2 are applicable to the above required Frequencies for performing inservice testing activities;

c. The provisions of SR 3.0.3 are applicable to inservice testing activities; and

d. Nothing in the ASME Boiler and Pressure Vessel Code shall be construed to supersede the requirements of any TS.

Prairie Island Unit 1 - Amendment No. 158 Units I and 2 5.0-12 Unit 2 - Amendment No. 149

Prograrns and ianuals 5.5 Programs and Manuals (continued) 5.5.8 Steam Generator (SG) Tube Surveillance Program Steam generator tubes in each unit shall be determined OPERABLE by the following:

a. Steam Generator Sample Selection and Inspection Each steam generator shall be determined OPERABLE in accordance with the in-service inspection schedule in Specification 5.5.8.c. The in-service inspection may be limited to one steam generator on a rotating schedule encompassing 6% of the tubes in the single steam generator, provided the previous inspections indicated that the two steam generators are performing in a like manner.

b. Steam Generator Tube Sample Selection and Inspection The steam generator tube minimum sample size, inspection result classification, and the corresponding action required shall be as specified in Tables 5.5.8-1 and 5.5.8-2. The in-service inspection of steam generator tubes shall be performed at the Frequencies specified in Specification 5.5.8.c and the inspected tubes shall be verified acceptable per the acceptance criteria of Specification 5.5.8.d. The tubes selected for each in-service inspection shall include at least 3% of the total number of tubes in all steam generators and at least 20% of the total number of sleeves in service in both steam generators; the tubes selected for these inspections shall be selected on a random basis except:

1. Where experience in similar plants with similar water chemistry indicates critical areas to be inspected, then at least 50% of the tubes inspected shall be from these critical areas.

2. The first sample of tubes selected for each in-service inspection (subsequent to the preservice inspection) of each steam generator shall include:

Prairie Island Unit 1 -Amendment No. 158 Units I and 2 5.0-13 Unit 2 - Amendment No. 149

Procranms and .Nianuals 5.5 Programs and Manuals 5.5.8 Steam Generator (SG) Tube Surveillance Program (continued)

(a) all tubes that previously had detectable wall penetrations

(> 20%) that have not been plugged or sleeve repaired in the affected area.

(b) tubes in those areas where experience has indicated potential problems.

(c) a tube inspection (pursuant to Specification 5.5.8.d.l.(h)) shall be performed on each selected tube. If any selected tube does not permit the passage of the eddy current probe for a tube inspection, this shall be recorded and an adjacent tube shall be selected and subjected to a tube inspection.

3. In addition to the sample required in Specification 5.5.8.b.2(a) through (c), all tubes which have had the F* or EF* criteria applied will be inspected in the F* and EF* regions of the roll expanded region. The region of these tubes below the F* and EF* regions may be excluded from the requirements of Specification 5.5.8.b.2(a).

4. The tubes selected as the second and third samples (if required by Tables 5.5.8-1 or 5.5.8-2) during each in-service inspection may be subjected to a partial tube or sleeve inspection provided:

(a) the tubes selected for these samples include the tubes from those areas of the tube sheet array where tubes with imperfections were previously found.

(b) the inspections include those portions of the tubes or sleeves where imperfections were previously found.

Prairie Island Unit I -Amendment No. 158 Units I and 2 5.0-14 Unit 2 - Amendment No. 149

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.8 Steam Generator (SG) Tube Surveillance Program (continued)

The results of each sample inspection shall be classified into one of the following three categories:

Category Inspection Results C-1 Less than 5% of the total tubes inspected are degraded tubes and none of the inspected tubes are defective.

C-2 One or more tubes, but not more than 1% of the total tubes inspected are defective, or between 5% and 10% of the total tubes inspected are degraded tubes.

C-3 More than 10% of the total tubes inspected are degraded tubes or more than 1% of the inspected tubes are defective.

Note: In all inspections, previously degraded tubes must exhibit significant (> 10%) further wall penetrations to be included in the above percentage calculations.

5. Indications left in service as a result of application of tube support plate voltage-based repair criteria shall be inspected by bobbin coil probe during all future refueling outages.

6. Implementation of the steam generator tube/tube support plate repair criteria requires a 100 percent bobbin coil inspection for hot leg and cold leg tube support plate intersections down to the lowest cold leg tube support plate with known outside diameter stress corrosion cracking (ODSCC) indications. The determination of the lowest cold leg tube support plate intersections having ODSCC indications shall be based on the performance of at least a 20 percent random sampling of tubes inspected over their full length.

Prairie Island Unit 1 -Amendment No. 158 Units I and 2 5.0-15 Unit 2 - Amendment No. 149

Programs and IManuals 5.5 5.5 Programs and Manuals 5.5.8 Steam Generator (SG) Tube Surveillance Program (continued)

c. Inspection Frequencies The above required in-service inspections of steam generator tubes shall be performed at the following Frequencies:

1. In-service inspections shall be performed at intervals of not less than 12 nor more than 24 calendar months after the previous inspection. If two consecutive inspections following service under AVT conditions, not including the preservice inspection, result in all inspection results falling into the C-I category or if two consecutive inspections demonstrate that previously observed degradation has not continued and no additional degradation has occurred, the inspection interval may be extended to a maximum of once per 40 months.

2. If the results of the in-service inspection of a steam generator conducted in accordance with Table 5.5.8-1 at 40 month intervals fall in Category C-3, the inspection frequency shall be increased to at least once per 20 months. The increase in inspection frequency shall apply until the subsequent inspections satisfy the criteria of Specification 5.5.8.c. 1; the interval may then be extended to a maximum of once per 40 months.

3. Additional, unscheduled in-service inspections shall be performed on each steam generator in accordance with the first sample inspection specified in Table 5.5.8-1 during the shutdown subsequent to any of the following conditions:

(a) primary-to-secondary tube leaks (not including leaks originating from tube-to-tube sheet welds) in excess of the limits of Specification 3.4.14.

(b) a seismic occurrence greater than the Operating Basis Earthquake.

Prairie Island Unit 1 -Amendment No. 158 Units 1 and 2 5.0-16 Unit 2 - Amendment No. 149

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.8 Steam Generator (SG) Tube Surveillance Program (continued)

(c ) a loss-of-coolant accident requiring actuation of the engineered safeguards.

(d) a main steam line or feedwater line break.

d. Acceptance Criteria

1. As used in this Specification:

(a) Imperfection means an exception to the dimensions, finish or contour of a tube from that required by fabrication drawings or specifications. Eddy-current testing indications below 20%

of the nominal tube wall thickness, if detectable, may be considered as imperfections.

(b) Degradation means a service-induced cracking, wastage, wear or general corrosion occurring on either inside or outside of a tube.

(c) Degraded Tube means a tube containing imperfections > 20%

of the nominal wall thickness caused by degradation.

(d) % Degradation means the percentage of the tube wall thickness affected or removed by degradation.

(e) Defect means an imperfection of such severity that it exceeds the repair limit. A tube containing a defect is defective.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 5.0-17 Unit 2 - Amendment No. 149

Progranms and NiManuals 5.5 5.5 Programs and Manuals 5.5.8 Steam Generator (SG) Tube Surveillance Program (continued)

(f) Repair Limit means the imperfection depth at or beyond which the tube shall be removed from service by plugging or repaired by sleeving because it may become unserviceable prior to the next inspection and is equal to 50% of the nominal tube wall thickness. If significant general tube thinning occurs, this criteria will be reduced to 40% wall penetration. This definition does not apply to the portion of the tube in the tubesheet below the F* distance provided the tube is not degraded (i.e., no indications of cracks) within the F* or EF* distance for F* or EF* tubes. The repair limit for the pressure boundary region of any sleeve is 25% of the nominal sleeve wall thickness. This definition does not apply to tube support plate intersections for which the voltage-based repair criteria are being applied. Refer to Specification 5.5.8.d.4 for the repair limit applicable to these intersections.

(g) Unserviceable describes the condition of a tube if it leaks or contains a defect large enough to affect its structural integrity in the event of an Operating Basis Earthquake, a loss-of-coolant accident, or a steam line or feedwater line break.

(h) Tube Inspection means an inspection of the steam generator tube from the point of entry (hot leg side) completely around the U-bend to the top support of the cold leg.

(i) Sleeving is the repair of degraded tube regions using a new Alloy 690 tubing sleeve inserted inside the parent tube and sealed at each end by welding or by replacing the lower weld in a full depth tubesheet sleeve with a hard rolled joint. The new sleeve becomes the pressure boundary spanning the original degraded tube region.

Prairie Island Unit 1 - Amendment No. 158 Units l and 2 5.0-18 Unit 2 - Amendment No. 149

Programs and Manuals 5_5 5.5 Programs and Manuals 5.5.8 Steam Generator (SG) Tube Surveillance Program (continued)

(j) F* Distance is the distance from the bottom of the hardroll transition toward the bottom of the tubesheet that has been conservatively determined to be 1.07 inches (not including eddy current uncertainty). The F* distance applies to roll expanded regions below the midplane of the tubesheet.

(k) F* Tube is a tube with degradation, below the F* distance, equal to or greater than 40%, and not degraded (i.e., no indications of cracking) within the F* distance.

(1) EF* Distance is the distance from the bottom of the upper hardroll transition toward the bottom of the tubesheet that has been conservatively determined to be 1.67 inches (not including eddy current uncertainty). EF* distance applies to roll expanded regions when the top of the additional roll expansion is 2.0 inches or greater down from the top of the tubesheet.

(m) EF* Tube is a tube with degradation, below the EF* distance, equal to or greater than 40%, and not degraded (i.e., no indications of cracking) within the EF* distance.

2. The steam generator shall be determined OPERABLE after completing the corresponding actions (plug or repair by sleeving all tubes exceeding the repair limit and all tubes containing through-wall cracks or classify as F* or EF* tubes) required by Tables 5.5.8-1 and 5.5.8-2.

3. Tube repair, after April 1, 1999, using Combustion Engineering welded sleeves shall be in accordance with the methods described in the following:

CEN-629-P, Revision 03-P, "Repair of Westinghouse Series 44 and 51 Steam Generator Tubes Using Leak Tight Sleeves".

Prairie Island Unit 1 - Amendment No. 158 Units I and 2 5.0-19 Unit 2 - Amendment No. 149

Programs and Nlanuals

5. 5 5.5 Programs and Manuals 5.5.8 Steam Generator (SG) Tube Surveillance Program (continued)

4. Tube Support Plate Repair Limit is used for the disposition of a steam generator tube for continued service that is experiencing predominantly axially oriented outside diameter stress corrosion cracking confined within the thickness of the tube support plates.

At tube support plate intersections, the repair limit is based on maintaining steam generator serviceability as described below:

(a) Steam generator tubes, whose degradation is attributed to outside diameter stress corrosion cracking within the bounds of the tube support plate with bobbin voltages less than or equal to 2.0 Volts will be allowed to remain in service.

(b) Steam generator tubes, whose degradation is attributed to outside diameter stress corrosion cracking within the bounds of the tube support plate with a bobbin voltage greater than 2.0 Volts, will be repaired or plugged, except as noted in Specification 5.5.8.d.4(c) below.

(c) Steam generator tubes, with indications of potential degradation attributed to outside diameter stress corrosion cracking within the bounds of the tube support plate with a bobbin voltage greater than 2.0 Volts but less than or equal to the upper voltage repair limit, may remain in service if a rotating pancake coil (or comparable examination technique) inspection does not detect degradation. Steam generator tubes, with indications of outside diameter stress corrosion cracking degradation with a bobbin voltage greater than the upper voltage repair limit will be plugged or repaired.

Prairie Island Unit 1 - Amendment No. 158 Units l and 2 5.0-20 Unit 2 - Amendment No. 149

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.8 Steam Generator (SG) Tube Surveillance Program (continued)

(d) If an unscheduled mid-cycle inspection is performed, the following mid-cycle repair limits apply instead of the limits in Specifications 5.5.8.d.4(a), (b) and (c). The mid-cycle repair limits are determined from the following equations:

VSL V\MURL

1. 0o

+NDE+lN(GCLGr I -CAt 2 CLc- At

.0)

VNILRL-VMIURL-(VURL-Where:

VURL = upper voltage repair limit VLRL = lower voltage repair limit VNIURL mid-cycle upper voltage repair limit based on time into cycle VMLRL - mid-cycle lower voltage repair limit based on VMURL and time into cycle At = length of time since last scheduled inspection during which VURL and VLRL were implemented Prairie Island Unit 1 - Amendment No. 158 Units I and 2 5.0-21 Unit 2 - Amendment No. 149

Programs and Manuals 5.5 Programs and Manuals 5.5.8 Steam Generator (SG) Tube Surveillance Program (continued)

CL = cycle length (time between two scheduled steam generator inspections)

VSL = structural limit voltage Gr = average growth rate per cycle length NDE = 95 percent cumulative probability allowance for nondestructive examination uncertainty (i.e., a value of 20 percent has been approved by the NRC)

Implementation of these mid-cycle repair limits should follow the same approach as described in Specifications 5.5.8.d.4(a),

(b) and (c).

Note: The upper voltage repair limit is calculated according to the methodology in Generic Letter 95-05 as supplemented.

Prairie Island Unit I - Amendment No. 158 Units 1 and 2 5.0-22 Unit 2 - Amendment No. 149

Progranis and Nianuals 5.5 5.5 Programs and Manuals (continued) 5.5.9 Ventilation Filter Testing Program (VFTP)

A program shall be established to implement the following required testing of the Control Room Special Ventilation System, Auxiliary Building Special Ventilation System, Shield Building Ventilation System, and the Spent Fuel Pool Special and Inservice Purge Ventilation System each operating cycle (18 months for shared systems).

Demonstrate for the Auxiliary Building Special Ventilation, Shield Building Ventilation, Control Room Special Ventilation, and Spent Fuel Pool Special and Inservice Purge Ventilation Systems that:

a. An inplace DOP test of the high efficiency particulate air (HEPA) filters shows a penetration and system bypass < 0.05% (for DOP, particles having a mean diameter of 0.7 microns);

b. A halogenated hydrocarbon test of the inplace charcoal adsorber shows a penetration and system bypass < 0.05% (for DOP, particles having a mean diameter of 0.7 microns);

c. A laboratory test of a sample of the charcoal adsorber, when obtained as described in Regulatory Guide 1.52, Revision 2, shows the methyl iodide penetration less than: 1) 15% penetration for Auxiliary Special Ventilation System, 2) 15% penetration for Shield Building Ventilation System, 3) 7.5% penetration for the Spent Fuel Pool Special and Inservice Purge System, and 4) 2.5% penetration for the Control Room Special Ventilation System when tested in accordance with ASTM D3803-1989 at a temperature of 30'C and 95% relative humidity (RH); and

d. The pressure drop across the combined HEPA filters and the charcoal adsorbers is less than 6 inches of water at the system flowrate +/- 10%.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 5.0-23 Unit 2 - Amendment No. 149

Programs and Nianuals 5.5 5.5 Programs and Manuals 5.5.9 Ventilation Filter Testing Program (VFTP) (continued)

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the VFTP test Frequencies.

5.5.10 Explosive Gas and Storage Tank Radioactivity Monitoring Program This program provides controls for potentially explosive gas mixtures contained in the waste gas holdup system, the quantity of radioactivity contained in gas storage tanks, and the quantity of radioactivity contained in unprotected outdoor liquid storage tanks.

The program shall include:

a. The limits for concentrations of oxygen in the waste gas holdup system and a surveillance program to ensure the limits are maintained. Such limits shall be appropriate to the system's design criteria;

b. A surveillance program to ensure that the quaraity of radioactivity contained in each gas storage tank is less than or equal to 78,800 Curies of noble gas (considered as dose equivalent Xe-133); and

c. A surveillance program to ensure that the quantity of radioactivity contained in each of the following tanks shall be limited to 10 Curies, excluding tritium and dissolved or entrained noble gases:

Condensate storage tanks Outside temporary tanks The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Explosive Gas and Storage Tank Radioactivity Monitoring Program surveillance Frequencies.

Prairie Island Unit 1 - Amendment No. 158 Units l and 2 5.0-24 Unit 2 - Amendment No. 149

Programs and Mianuals 5, 5 5.5 Programs and Manuals (continued) 5.5.11 Diesel Fuel Oil Testing Program A diesel fuel oil testing program to implement required testing of both new fuel oil and stored fuel oil shall be established. The program shall include sampling and testing requirements, and acceptance criteria, all in accordance with the limits specified in Table 1 of ASTM D975-77 when checked for viscosity, water, and sediment. Acceptability of new fuel oil shall be determined prior to addition to the safeguards storage tanks.

Testing of diesel fuel oil stored in the safeguards storage tanks shall be performed at least every 3 1 days.

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Diesel Fuel Oil Testing Program test Frequencies.

5.5.12 Technical Specifications (TS) Bases Control Program This program provides a means for processing changes to the Bases of these Technical Specifications.

a. Changes to the Bases of the TS shall be made under appropriate administrative controls and reviews;

b. Licensees may make changes to Bases without prior NRC approval provided the changes do not require either of the following:

1. a change in the TS incorporated in the license, or

2. a change to the USAR or Bases that requires NRC approval pursuant to 10 CFR 50.59;

c. The Bases Control Program shall contain provisions to ensure that the Bases are maintained consistent with the USAR; and Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 5.0-25 Unit 2 - Amendment No. 149

Programs and Manuals 5.5 Programs and Manuals 5.5.12 Technical Specifications (TS) Bases Control Program (continued)

d. Proposed changes that meet the criteria of Specification 5.5.12 b above shall be reviewed and approved by the NRC prior to implementation.

Changes to the Bases implemented without prior NRC approval shall be provided to the NRC on a frequency consistent with USAR updates.

5.5.13 Safety Function Determination Program (SFDP)

This program ensures loss of safety function is detected and appropriate actioils taken. Upon entry into LCO 3.0.6, an evaluation shall be made to determine if loss of safety function exists. Additionally, other appropriate actions may be taken as a result of the support system inoperability and corresponding exception to entering supported system Conditions and Required Actions. This program implements the requirements of LCO 3.0.6. The SFDP shall contain the following:

a. Provisions for cross train checks to ensure a loss of the capability to perform the safety function assumed in the accident analysis does not go undetected;

b. Provisions for ensuring the plant is maintained in a safe condition if a loss of function condition exists;

c. Provisions to ensure that an inoperable supported system's Completion Time is not inappropriately extended as a result of multiple support system inoperabilities; and

d. Other appropriate limitations and remedial or compensatory actions.

Prairie Island Unit 1 - Amendment No. 158 Units I and 2 5.0-26 Unit 2 - Amendment No. 149

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.13 Safety Function Determination Program (SFDP) (continued)

A loss of safety function exists when, assuming no concurrent single failure, no concurrent loss of offsite power or no concurrent loss of onsite diesel generator(s), a safety function assumed in the accident analysis cannot be performed. For the purpose of this program, a loss of safety function may exist when a support system is inoperable, and:

a. A required system redundant to the system(s) supported by the inoperable support system is also inoperable; or

b. A requircd system redundant to the system(s) in turn supported by the inoperable supported system is also inoperable; or

c. A required system redundant to the inoperable support system(s) for the supported systems (a) and (b) above is also inoperable.

The SFDP identifies where a loss of safety function exists. If a loss of safety function is determined to exist by this program, the appropriate Conditions and Required Actions of the LCO in which the loss of safety function exists are required to be entered. When a loss of safety function is caused by the inoperability of a single Technical Specification support system, the appropriate Conditions and Required Actions to enter are those of the support system.

5.5.14 Containment Leakage Rate Testing Program

a. A program shall be established to implement the leakage rate testing of the containment as required by 10 CFR 50.54(o) and 10 CFR 50, Appendix J, Option B, as modified by approved exemptions. This program shall be in accordance with the guidelines contained in Regulatory Guide 1.163, "Performance-Based Containment Leak-Test Program," dated September 1995.

Prairie Island Unit 1 -Amendment No. 158 Units 1 and 2 5.0-27 Unit 2 - Amendment No. 149

Programs and Mianuals 5.5 5.5 Programs and Manuals 5.5.14 Containment Leakage Rate Testing Program (continued)

b. The peak calculated containment internal pressure for the design basis loss of coolant accident is less than the containment internal design pressure, P,, of 46 psig.

c. The maximum allowable primary containment leakage rate, La, at P,,

shall be 0.25% of primary containment air weight per day. For pipes connected to systems that are in the auxiliary building special ventilation zone, the total leakage shall be less than 0.1% of primary containment air weight per day at pressure P,. For pipes connected to ystems that are exterior to both the shield building and the auxiliary building special ventilation zone, the total leakage past isolation valves shall be less than 0.0 1% of primary containment air weight per day at pressure P,.

d. Leakage Rate acceptance criteria are:

1. Primary containment leakage rate acceptance criterion is :< 1.0 La.

Prior to unit startup, following testing in accordance with the program, the combined leakage rate acceptance criteria are !<0.60 La for all components subject to Type B and Type C tests and

< 0.75 La for Type A tests.

2. Air lock testing acceptance criteria are:

a) Overall air lock leakage rate is !<0.05 La when tested at > 46 psig.

b) For each door intergasket test, leakage rate is :< 0.01 La when pressurized to _>10 psig.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 5.0-28 Unit 2 - Amendment No. 149

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.14 Containment Leakage Rate Testing Program (continued)

e. The provisions of SR 3.0.3 are applicable to the Containment Leakage Rate Testing Program.

f. Nothing in these Technical Specifications shall be construed to modify the testing Frequencies required by 10 CFR 50, Appendix J.

5.5.15 Battery Monitorin2 and Maintenance Program This Program provides for restoration and maintenance of the 125V plant safeguards batteries and service building batteries, which may be used instead of the safeguards batteries during shutdown conditions in accordance with manufacturer's recommendations, as follows:

a. Actions to restore battery cells with float voltage < 2.13 V will be in accordance with manufacturer's recommendations, and

b. Actions to equalize and test battery cells that had been discovered with electrolyte level below the minimum established design limit.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 5.0-29 Unit 2 - Amendment No. 149

Programs and Manuals 5.5 Table 5.5.8-1 STEAM GENERATOR TUBE INSPECTION 1st SAMPLE INSPECTION 2 nd SAMPLE INSPECTION 3 SAMPLE INSPECTION Sample Size I Result Action Required Result Action Required Result Action Required A minimum C-1 None N/A N/A N/A N/A t ir 1 II +

of S Tubes C-2 Repair defective tubes C-1 None N/A N/A per S.G.

and inspect additional 2S C-2 Repair defective C-1 None tubes in this S.G.

tubes and inspect C-2 Repair defective additional 4S tubes tubep in this S.G. tubes C-3 Perform action for C-3 result of first sample C-3 Perform action for N/A N/A C-3 result of first sample

_____________ I. .1+ 1+

C-3 Inspect all tubes in this All other S.G.s are None N/A N/A S.G., Repair defective C-1 i 4 -- -------------

tubes and inspect 2S Some S.G.s C-2 but Perforn action for N/A N/A tubes in each other S.G. no additional S.G. C-2 result of second Prompt notification to are C-3 sample NRC ---- -

-- t.

Additional S.G. is Inspect all tubes in N/A N/A C-3 each S.G. and repair defective tubes.

Prompt notification to NRC.

S=3%; When two steam generators are inspected during that outage.

S=6%; When one steam generator is inspected during that outage.

Prairie Island Unit I - Amendment No. 158 Units 1 and 2 5.0-30 Unit 2 - Amendment No. 149

Programs and Manuals 5.5 Table 5.5.8-2 STEAM GENERATOR TUBE SLEEVE INSPECTION I"t Sample Inspection 22d Sample Inspection Sample Size Result Action Required Result Action Required A minimum C-I None N/A N/A of 20% of C-2 Inspect all remaining tube C-1 None Tube Sleeves sleeves in this S.G. and plug or C-2 Plug or repair defective sleeved (1) repair defective sleeved tubes. tubes C-3 Perform action for C-3 result of first sample C-3 Inspect all tube sleeves in this The other S.G. None S.G., inspect 20% of the tube is C-1 sleeves in the other S.G., and The other S.G. Perform action for C-2 result of first plug or repair defective sleeved is C-2 sample tubes The other S.G. Inspect all tube sleeves in each S.G.

is C-3 and plug or repair defective sleeved tubes (1) Each type of sleeve is considered a separate population for detenrmination of scope expansion Prairie Island Unit I - Amendment No. 158 Units 1 and 2 5.0-31 Unit 2 - Amendment No. 149

Reporting Requirements 5.6 5.0 ADMINISTRATIVE CONTROLS 5.6 Reporting Requirements The following reports shall be submitted in accordance with 10 CFR 50.4.

5.6.1 Occupational Exposure Report

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

A single submittal may be made for the plant. The submittal should combine sections common to both units.

S A tabulation on an annual basis of the number of station, utility, and other personnel (including contractors) for whom monitoring was performed, receiving an annual deep dose equivalent > 100 mrem and the associated collective deep dose equivalent (reported in person-rem) according to work and job functions, e.g., reactor operations and surveillance, inservice inspection, routine maintenance, special maintenance (describe maintenance), waste processing, and refueling. This tabulation supplements the requirements of 10 CFR 20.2206. The dose assignments to various duty functions may be estimated based on pocket ionization chamber, thermoluminescent dosimeter (TLD), electronic dosimeter, or film badge measurements. Small exposures totaling < 20% of the individual total doseneed not be accounted for. In the aggregate, at least 80% of the total deep dose equivalent received from external sources should be assigned to specific major work functions. The report covering the previous calendar year shall be submitted by April 30 of each year.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 5.0-32 Unit 2 - Amendment No. 149

Reporting Requirements 5.6 5.6 Reporting Requirements (continued) 5.6.2 Annual Radiological Environmental Monitoring Report

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

A single submittal may be made for the plant. The submittal should combine sections common to both units.

S...........................................................................................

The Annual Radiological Environmental Monitoring Report covering the operation of the plant during the previous calendar year shall be submitted by May 15 of each year. The report shall include summaries, interpretations, and analyses of trends of the results of the radiological environmental monitoring program for the reporting period. The material provided shall be consistent with the objectives outlined in the Offsite Dose Calculation Manual (ODCM), and in 10 CFR 50, Appendix I, Sections IV.B.2, IV.B.3, and IV.C.

The Annual Radiological Environmental Monitoring Report shall include summarized and tabulated results, in the format of Regulatory Guide 4.8, December 1975, of all radiological environmental samples taken during the report period. In the event that some individual results are not available for inclusion with the report, the report shall be submitted noting and explaining the reasons for the missing results. The missing data shall be submitted in a supplementary report as soon as possible.

The report shall also include the following: a summary description of the radiological environmental monitoring program; a map of sampling locations keyed to a table giving distances and directions from the reactor site; and the results of licensees participation in the Interlaboratory Comparison Program defined in the ODCM.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 5.0-33 Unit 2 - Amendment No. 149

Reporting Requirements 5.6 5.6 Reporting Requirements (continued) 5.6.3 Radioactive Effluent Report

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

A single submittal may be made for the plant. The submittal shall combine sections common to both units.

S...........................................................................................

The Radioactive Effluent Report covering the operation of the plant during the previous calendar year shall be submitted by May 15 of each year. The report shall include a summary of the quantities of radioactive liquid and gaseous effluents and solid waste released from the plant. The material provided shall be consistent with the objectives outlined in the ODCM and in corformance with 10 CFR 50.36a and 10 CFR 50, Appendix I, Section IV.B. 1.

5.6.4 Monthly Operating Reports Routine reports of operating statistics and shutdown experience shall be submitted on a monthly basis no later than the 15th of each month following the calendar month covered by the report.

5.6.-,) CuRE OPERATING LIMITS REPORT (COLR)

a. Core operating limits shall be established prior to each reload cycle, or prior to any remaining portion of a reload cycle, and shall be documented in the COLR for the following:

LCO 3.1.1, "SHUTDOWN MARGIN (SDM)";

LCO 3.1.3, "Isothermal Temperature Coefficient (ITC)";

LCO 3.1.5, "Shutdown Bank Insertion Limits";

LCO 3.1.6, "Control Bank Insertion Limits";

LCO 3.1.8, "PHYSICS TESTS Exceptions - MODE 2";

Prairie Island Unit I - Amendment No. 158 Units 1 and 2 5.0-34 Unit 2 - Amendment No. 149

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.5 CORE OPERATING LIMITS REPORT (COLR) (continued)

LCO 3.2.1, "1HeatFlux Hot Channel Factor (FQ(Z))"Y LCO 3.2.2, 'Nuclear Enthalpy Rise Ilot Channel Factor (F.,);

LCO 3.2.3, "AXIAL FLUX DIFFERENCE (AFD)",

LCO 3.4.1. "'RCS Pressure., Temperature, and Flow - Departure from Nucleate Boiling (DNB) Limits": and LCO 3.9.1, "Boron Concentration".

b. The analytical methods used to determine the core operating limits shall be those previously reviewed and approved by the NRC, specifically those described in the following documents:

1. NSPNAD-8101-PA, "Qualification of Reactor Physics Methods for Application to PI Units" (latest approved version);

2. NSPNAD-8 102-PA, "Prairie Island Nuclear Power Plant Reload Safety Evaluation Methods for Application to PI Units"(latest approved version);

3. NSPNAD-97002-PA, "Northern States Power Company's "Steam Line Break Methodology", (latest approved version);

4. WCAP-9272-P-A, "Westinghouse Reload Safety Evaluation Methodology", July, 1985;

5. WCAP-10054-P-A, "Westinghouse Small Break ECCS Evaluation Model using the NOTRUMP Code", August, 1985;

6. WCAP-10924-P-A, "Westinghouse Large Break LOCA Best-Estimate Methodology", December, 1988;

7. WCAP-10924-P-A, Volume 1, Addendum 4, "Westinghouse Large Break LOCA Best Estimate Methodology", August, 1990; Prairie Island Unit 1 - Amendment No. 158 Units I and 2 5.0-35 Unit 2 - Amendment No. 149

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.5 CORE OPERATING LIMITS REPORT (COLR) (continued)

8. XN-NF-77-57 (A), XN-NF-77-57, Supplement 1 (A), "Exxon Nuclear Power Distribution Control for Pressurized Water Reactors Phase II", May. 1981:

9. WCAP-13677, "10 CFR 50.46 Evaluation Model Report:

W-COBRA/TRAC 2-Loop Upper Plenum Injection Model Update to Support ZIRLOTNt Cladding Options", April 1993 (approved by NRC SE dated November 26, 1993);

10. NSPNAD-93003-A, -Transient Power Distribution Methodology".

(latest approved version);

11. NAD-PI-003, "Prairie Island Nuclear Power Plant Required Shutdown Margin During Physics Tests," (approved by NRC SE dated July 30, 2002); and

12. NAD-PI-004, "Prairie Island Nuclear Power Plant F "'(Z) Penalty With Increasing [F (Z)/ K(Z)] Trend," approved by NRC SE dated July 30, 2002).

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

d. The COLR, including any midcycle revisions or supplements, shall be provided upon issuance for each reload cycle to the NRC.

5.6.6 Reactor Coolant System (RCS) PRESSURE AND TEMPERATURE LIMITS REPORT (PTLR)

a. RCS pressure and temperature limits for heat-up, cooldown, low temperature operation, criticality, and hydrostatic testing, OPPS Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 5.0-36 Unit 2 - Amendment No. 149

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.6 Reactor Coolant System (RCS) PRESSURE AND TEMPERATURE LIMITS REPORT (PTLR) (continued) arming, PORV lift settings and Safety Injection Pump Disable Temperature as well as heatup and cooldown rates shall be established and documented in the PTLR for the following:

LCO 3.4.3, "RCS Pressure and Temperature (P!T) Limits":

LCO 3.4.6, "RCS Loops - MODE 4";

LCO 3.4.7, "RCS Loops - MODE 5, Loops Filled";

LCO 3.4.10, "Pressurizer Safety Valves";

LCO 3.4.12, "Low Temperature Overpressure Protection (LTOP)

Reactor Coolant System Cold Leg Temperature (RCSCLT) > Safety Injection (SI) Pump Disable Temperature";

LCO 3.4.13, "Low Temperature Overpressure Protection (LTOP)

Reactor Coolant System Cold Leg Temperature (RCSCLT) !<Safety Injection (SI) Pump Disable Temperature"; and LCO 3.5.3, "ECCS - Shutdown".

b. The analytical methods used to determine the RCS pressure and temperature limits and Cold Overpressure Mitigation System setpoints shall be those previously reviewed and approved by the NRC, specifically those described in the following document:

WCAP-14040-NP-A, Revision 2, "Methodology Used to Develop Cold Overpressure Mitigating System Setpoints and RCS Heatup and Cooldown Limit Curves" (includes any exemption granted by NRC to ASME Code Case N-514).

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

Changes to the curves, setpoints, or parameters in the PTLR resulting from new or additional analysis of beltline material properties shall be submitted to the NRC prior to issuance of an updated PTLR.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 5.0-37 Unit 2 - Amendment No. 149

Reporting Requiremcnts 5.6 5.6 Reporting Requirements (continu'.d) 5.6.7 Steam Generator Tube Inspection Report

1. Following each in-service inspection of steam generator tubes, if there are any tubes requiring plugging or sleeving, the number of tubes plugged or sleeved in each steam generator shall be reported to the Commission within 15 days.

2. The results of steam generator tube in-service inspections shall be included with the summary reports of ASME Code Section XI inspections submitted within 90 days of the end of each refueling outage. Results of steam generator tube in-service inspections not associated with a refueling outage shall be submitted within 90 days of the completion of the inspection. These reports shall include: (1) number and extent of tubes inspected, (2) location and percent of wall-thickness penetration for each indication of an imperfection, and (3) identification of tubes plugged or sleeved.

3. Results of steam generator tube inspections which fall into Category C-3 require notification to the Commission prior to resumption of plant operation, and reporting as a special report to the Commission within 30 days. This special report shall provide a description of investigations conducted to determine cause of the tube degradation.

and corrective measures taken to prevent recurrence.

4. The results of inspections performed under Specification 5.5.8.b for all tubes that have defects below the F* or EF* distance, and were not plugged, shall be reported to the Commission within 15 days following the inspection. The report shall include:

a. Identification of F* and EF* tubes, and

b. Location and extent of degradation.

Prairie Island Unit 1 - Amendment No. 158 Units l and 2 5.0-38 Unit 2 - Amendment No. 149

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.7 Steam Generator Tube Inspection Report (continued)

5. For implementation of the voltage-based repair criteria to tube support plate intersections, notify the NRC staff prior to returning the steam generators to service should any of the following conditions arise:

a. If estimated leakage based on the projected end-of-cycle (or if not practical, using the actual measured end-of-cycle) voltage distribution exceeds the leak limit (determined from the licensing basis dose calculation for the postulated main steamline break) for the next operating cycle.

b. If circumferential crack-like indications are detected at the tube support plate intersections.

c. If indications are identified that extend beyond the confines of the tube support plate.

d. If indications are identified at the tube support plate elevations that are attributable to primary water stress corrosion cracking.

e. If the calculated conditional burst probability based on the projected end-of-cycle (or if not practical, using the actual measured end-of-cycle) voltage distribution exceeds I E-02, notify the NRC and provide an assessment of the safety significance of the occurrence.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 5.0-39 Unit 2 - Amendment No. 149

Reporting Requirements 5.6 5.6 Reporting Requirements (continued) 5.6.8 EM Report When a report is required by Condition C or J of LCO 3.3.3, "Event Monitoring (EM) Instrumentation," a report shall be submitted within the following 14 days.

The report shall outline the preplanned alternate method of monitoring, the cause of the inoperability, and the plans and schedule for restoring the instrumentation channels of the Function to OPERABLE status.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 5.0-40 Unit 2 - Amendment No. 149

High Radiation Area 5.7 5.0 ADMINISTRATIVE CONTROLS 5.7 High Radiation Area As provided in paragraph 20.1601(c) of 10 CFR Part 20, the following controls shall be applied in place of the controls required by paragraph 10 CFR 20.1601(a) and (b) of 10 CFR 20:

5.7.1 High Radiation Areas accessible to personnel in which radiation levels could result in an individual receiving a deep dose equivalent less than 1.0 rem in one hour at 30 centimeters from the radiation source or from any surface that the radiation penetrates

a. Each entryway to such an area shall be barricaded and conspicuously posted as a high radiation area. Such barricades may be opened as necessary to permit entry or exit of personnel or equipment.

b. Access to, and activities in each such area shall be controlled by means of a Radiation Work Permit (RWP) or equivalent that includes specification of radiation dose rates in the immediate work area(s) and other appropriate radiation protection equipment and measures.

c. Individuals qualified in radiation protection procedures and personnel continuously escorted by such individuals may be exempted from the requirement for an RWP or equivalent while performing their assigned duties provided they are otherwise following plant radiation protection procedures for entry to, exit from, and work in such areas.

d. Each individual or group entering such an area shall possess:

1. A radiation monitoring device that continuously displays radiation dose rates in the area; or

2. A radiation monitoring device that continuously integrates the radiation dose rates in the area and alarms when the device's dose alarm setpoint is reached, with an appropriate alarm setpoint; or Prairie Island Unit I - Amendment No. 158 Units I and 2 5.0-41 Unit 2 - Amendment No. 149

1-1igh Radiation Area 5.7 5.7 High Radiation Area 5.7.1 High Radiation Areas accessible to personnel in which radiation levels could result in an individual receiving a deep dose equivalent less than 1.0 rem in one hour at 30 centimeters from the radiation source or from any surface that the radiation penetrates (continued)

3. A radiation monitoring device that continuously transmits dose rate and cumulative dose information to a remote receiver monitored by radiation protection personnel responsible for controlling personnel radiation exposure within the area; or

4. A self-reading dosimeter (e.g., pocket ionization chamber or electronic dosimeter) and, (i) Be under the surveillance, as specified in the RWP or equivalent, while in the area, of an individual qualified in radiation protection procedures, equipped with a radiation monitoring device that continuously displays radiation dose rates in the area, who is responsible for controlling personnel exposure within the area; or (ii) Be under the surveillance as specified in the RWP or equivalent, while in the area, by means of closed circuit television, of personnel qualified in radiation protection procedures, responsible for controlling personnel radiation exposure in the area, and with the means to communicate with individuals in the area who are covered by such surveillance.

e. Except for individuals qualified in radiation protection procedures, or personnel continuously escorted by such individuals, entry into such areas shall be made only after dose rates in the area have been determined and entry personnel are knowledgeable of them. These continuously escorted personnel will receive a pre-job briefing prior to entry into such areas. This dose rate determination, knowledge, and pre-job briefing does not require documentation prior to initial entry.

Prairie Island Unit 1 - Amendment No. 158 Units l and 2 5.0-42 Unit 2 - Amendment No. 149

High Radiation Area 5.7 5.7 High Radiation Area (continued) 5.7.2 High Radiation Areas accessible to personnel in which radiation levels could result in an individual receiving a deep dose equivalent in excess of 1.0 rem in one hour at 30 centimeters from the radiation source or from any surface that the radiation penetrates, but less than 500 rad in one hour at one meter from the source

a. Each entryway to such an area shall be conspicuously posted as a high radiation area and shall be provided with a locked or continuously guarded door or gate that prevents unauthorized entry, and, in addition:

1. All such door and gate keys shall be maintained under the administrative control of the shift supervisor, radiation protection manager, or their designee.

2. Doors and gates shall remain locked except during periods of personnel or equipment entry or exit.

b. Access to, and activities in, each such area shall be controlled by means of an RWP or equivalent that includes specification of radiation dose rates in the immediate work area(s) and other appropriate radiation protection equipment and measures.

c. Individuals qualified in radiation protection procedures may be exempted from the requirement for an RWP or equivalent while performing radiation surveys in such areas provided they are otherwise following plant radiation protection procedures for entry to, exit from, and work in such areas.

d. Each individual or group entering such an area shall possess:

1. A radiation monitoring device that continuously integrates the radiation dose rates in the area and alarms when the device's dose alarm setpoint is reached, with an appropriate alarm setpoint; or Prairie Island Unit 1 -Amendment No. 158 Units I and 2 5.0-43 Unit 2 - Amendment No. 149

High Radiation Area 5.7 5.7 High Radiation Area 5.7.2 High Radiation Areas accessible to personnel in which radiation levels could result in an individual receiving a deep dose equivalent in excess of 1.0 rem in one hour at 30 centimeters from the radiation source or from any surface that the radiation penetrates, but less than 500 rad in one hour at one meter from the source (continued)

2. A radiation monitoring device that continuously transmits dose rate and cumulative dose information to a remote receiver monitored by radiation protection personnel responsible for controlling personnel radiation exposure within the area with the means to communicate with and control every individual in the area; or

3. A self-reading dosimeter (e.g., pocket ionization chamber or electronic dosimeter) and, (i) Be under the surveillance, as specified in the RWP or equivalent, while in the area, of an individual qualified in radiation protection procedures, equipped with a radiation monitoring device that continuously displays radiation dose rates in the area, who is responsible for controlling personnel exposure within the area; or (ii) Be under the surveillance as specified in the RWP or equivalent, while in the area, by means of closed circuit television, of personnel qualified in radiation protection procedures, responsible for controlling personnel radiation exposure in the area, and with the means to communicate with and control every individual in the area.

4. In those cases where options (2) and (3) above are impractical or determined to be inconsistent with the "As Low As is Reasonably Achievable" principle, a radiation monitoring device shall be used that continuously displays radiation dose rates in the area.

Prairie Island Unit 1 - Amendment No. 158 Units 1 and 2 5.0-44 Unit 2 - Amendment No. 149

High Radiation Area 5,7 5.7 High Radiation Area 5.7.2 High Radiation Areas accessible to personnel in which radiation levels could result in an individual receiving a deep dose equivalent in excess of 1.0 rem in one hour at 30 centimeters from the radiation source or from any surface that the radiation penetrates, but less than 500 rad in one hour at one meter from the source (continued)

e. Except for individuals qualified in radiation protection procedures, or personnel continuously escorted by such individuals, entry into such areas shall be made only after dose rates in the area have been determined and entry personnel are knowledgeable of them. These continuously escorted personnel will receive a pre-job briefing prior to entry into such areas. This dose rate determination, knowledge, and pre-job briefing does not require documentation prior to initial entry.

f. Such individual areas that are located within a larger area where no enclosure exists for the purpose of locking and where no enclosure can be reasonably constructed around the individual area, that individual area need not be controlled by a locked door or gate, nor continuously guarded, but shall be barricaded, conspicuously posted, and a flashing light shall be activated at the area as a warning device.

Prairie Island Unit I - Amendment No. 158 Units 1 and 2 5.0-45 Unit 2 - Amendment No. 149

v t e Letter Sequence Other
TAC:MB0695, Ventilation System Envelope Allowed Outage Time (Approved, Closed) TAC:MB0696, Ventilation System Envelope Allowed Outage Time (Approved, Closed)
Initiation Acceptance... Supplement, Supplement, Supplement Administration Questions 8 January 2002 Answers Results Approval, Approval, Approval, Approval, Approval, Approval, Approval Other: ML021830089, ML022070613, ML022070658, ML022140359, ML022140370, ML022140394, ML022140412, ML022210043, ML022210054
MONTHYEAR2002-03-06 [Table View]

ML022210054

Text

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