Text

Tech Spec Pages for Amendment 199 Changes to Technical Specifications to Replace the Current Accident Source Term Used in Design Basis Radiological Analyses
	ML063280053
Person / Time
Site:	Columbia
Issue date:	11/27/2006
From:	; NRC/NRR/ADRO/DORL/LPLIV
To:	;
	Terao D, NRR/ADRO/DORL/LPL4, 415-1302
References
	TAC MC4570
	Download: ML063280053 (36)
	v • d • e

TABLE OF CONTENTS 3.3 INSTRUMENTATION (continued) 3.3.5.2 Reactor Core Isolation Cooling (RCIC) System Instrumentation . . . . . . . . . . . . . . 3.3.5.2-1 3.3.6.1 Primary Containment Isolation Instrumentation 3.3.6.1-1 3.3.6.2 Secondary Containment Isolation Instrumentation 3.3.6.2-1 3.3.7.1 Control Room Emergency Filtration (CREF) System Instrumentation . . . . . . . . . . . . . . 3.3.7.1-1 3.3.8.1 Loss of Power (LOP) Instrumentation ...... 3.3.8.1-1 3.3.8.2 Reactor Protection System (RPS) Electric Power Monitoring ........ ................. 3.3.8.2-1 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.1 Recirculation Loops Operating .......... 3.4.1-1 3.4.2 Jet Pumps . . . . . . . . . . . . . . . . . . . . 3.4.2-1 3.4.3 Safety/Relief Valves (SRVs) - > 25% RTP 3.4.3-1 3.4.4 Safety/Relief Valves (SRVs) - < 25% RTP ..... 3.4.4-1 3.4.5 RCS Operational LEAKAGE ............. 3.4.5-1 3.4.6 RCS Pressure Isolation Valve (PIV) Leakage .... 3.4.6-1 3.4.7 RCS Leakage Detection Instrumentation ...... 3.4.7-1 3.4.8 RCS Specific Activity . . . . . . . . . . . . . . 3.4.8-1 3.4.9 Residual Heat Removal (RHR) Shutdown Cooling System-Hot Shutdown ..................... 3.4.9-1 3.4.10 Residual Heat Removal (RHR) Shutdown Cooling System-Cold Shutdown ............ 3.4.10-1 3.4.11 RCS Pressure and Temperature (P/T) Limits .... 3.4.11-1 3.4.12 Reactor Steam Dome Pressure ........... 3.4.12-1 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.1 ECCS-Operating . . . . . . . . . . . . . . . . . 3.5.1-1 3.5.2 ECCS- Shutdown ........ .................. 3.5.2-1 3.5.3 RCIC System . . . . . . . . . . . . . . . . . . . 3.5.3-1 3.6 CONTAINMENT SYSTEMS 3.6.1.1 Primary Containment . . . . . . . . . . . . . . . 3.6.1.1-1 3.6.1.2 Primary Containment Air Lock ... ............. 3.6.1.2-1 3.6.1.3 Primary Containment Isolation Valves (PCIVs) . . . 3.6.1.3-1 3.6.1.4 Drywell Air Temperature ............. 3.6.1.4-1 3.6.1.5 Residual Heat Removal (RHR) Drywell Spray .. 3.6.1.5-1 3.6.1.6 Reactor Building-to-Suppression Chamber Vacuum Breakers . . . . . . . . . . . . . . . 3.6.1.6-1 3.6.1.7 Suppression Chamber-to-Drywell Vacuum Breakers 3.6.1.7-1 3.6.2.1 3.6.2.2 Suppression Pool Average Temperature ..........

Suppression Pool Water Level .... ............

3.6.2.1-1 3.6.2.2-1 I 3.6.2.3 Residual Heat Removal (RHR) Suppression Pool Cooling . . . . . . . . . . . . . . . . . . . 3.6.2.3-1 (continued)

Columbia Generating Station ii Amendment No. 149,IS0,I9-6 199

TABLE OF CONTENTS 3.6 CONTAINMENT SYSTEMS (continued) 3.6.3.1 Deleted 3.6.3.2 Primary Containment Atmosphere Mixing System . . . 3.6.3.2-1 3.6.3.3 Primary Containment Oxygen Concentration ........ .. 3.6.3.3-1 3.6.4.1 Secondary Containment ....... ............... ... 3.6.4.1-1 3.6.4.2 Secondary Containment Isolation Valves (SCIVs) . . 3.6.4.2-1 3.6.4.3 Standby Gas Treatment (SGT) System ............ ... 3.6.4.3-1 3.7 PLANT SYSTEMS 3.7.1 Standby Service Water (SW) System and Ultimate Heat Sink (UHS) ....... ............ 3.7.1-1 3.7.2 High Pressure Core Spray (HPCS) Service Water (SW) System ......... .................. ... 3.7.2-1 3.7.3 Control Room Emergency Filtration (CREF) System . 3.7.3-1 3.7.4 Control Room Air Conditioning (AC) System ..... ... 3.7.4-1 3.7.5 Main Condenser Offgas ....... ............... ... 3.7.5-1 3.7.6 Main Turbine Bypass System ..... ............. ... 3.7.6-1 3.7.7 Spent Fuel Storage Pool Water Level ...... ........ 3.7.7-1 3.8 ELECTRICAL POWER SYSTEMS 3.8.1 AC Sources-Operating ........... ............... 3.8.1-1 3.8.2 AC Sources-Shutdown ............................ 3.8.2-1 3.8.3 Diesel Fuel Oil, Lube Oil. and Starting Air . .. 3.8.3-1 3.8.4 DC Sources-Operating ........... ............... 3.8.4-1 3.8.5 DC Sources-Shutdown .......... ................ 3.8.5-1 3.8.6 Battery Cell Parameters ........ ............ ... 3.8.6-1 3.8.7 Distribution Systems-Operating .... .......... ... 3.8.7-1 3.8.8 Distribution Systems-Shutdown .... ........... ... 3.8.8-1 3.9 REFUELING OPERATIONS 3.9.1 Refueling Equipment Interlocks .... ........... ... 3.9.1-1 3.9.2 Refuel Position One-Rod-Out Interlock ......... ... 3.9.2-1 3.9.3 Control Rod Position .......... ................ 3.9.3-1 3.9.4 Control Rod Position Indication .... .......... ... 3.9.4-1 3.9.5 Control Rod OPERABILITY-Refueling ............ ... 3.9.5-1 3.9.6 Reactor Pressure Vessel (RPV) Water Level-Irradiated Fuel ........ ............. 3.9.6-1 3.9.7 Reactor Pressure Vessel (RPV) Water Level-New Fuel or Control Rods ........... .. 3.9.7-1 3.9.8 Residual Heat Removal (RHR)-High Water Level . . 3.9.8-1 3.9.9 Residual Heat Removal (RHR)-Low Water Level . . . 3.9.9-1 3.9.10 Decay Time .......... ..................... ... 3.9.10-1 3.10 SPECIAL OPERATIONS 3.10.1 Inservice Leak and Hydrostatic Testing Operation . 3.10.1-1 3.10.2 Reactor Mode Switch Interlock Testing ......... ... 3.10.2-1 3.10.3 Single Control Rod Withdrawal -Hot Shutdown . . . . 3.10.3-1 (continued)

Columbia Generation Station i ii Amendment No. 149,1*&9*89 199

Definitions 1.1 1.1 Definitions (continued)

CHANNEL FUNCTIONAL TEST A CHANNEL FUNCTIONAL TEST shall be the injection of a simulated or actual signal into the channel as close to the sensor as practicable to verify OPERABILITY, including required alarm, interlock, display, and trip functions, and channel failure trips. The CHANNEL FUNCTIONAL TEST may be performed by means of any series of sequential, overlapping, or total channel steps so that the entire channel is tested.

CORE ALTERATION CORE ALTERATION shall be the movement of any fuel, sources, or reactivity control components within the reactor vessel with the vessel head removed and fuel in the vessel. The following exceptions are not considered to be CORE ALTERATIONS:

a. Movement of source range monitors, local power range monitors, intermediate range monitors, traversing incore probes, or special movable detectors (including undervessel replacement);

and

b. Control rod movement, provided there are no fuel assemblies in the associated core cell.

Suspension of CORE ALTERATIONS shall not preclude completion of movement of a component to a safe position.

CORE OPERATING LIMITS The COLR is the unit specific document that REPORT (COLR) provides cycle specific parameter limits for the current reload cycle. These cycle specific limits shall be determined for each reload cycle in accordance with Specification 5.6.3. Plant operation within these limits is addressed in individual Specifications.

DOSE EQUIVALENT 1-131 DOSE EQUIVALENT 1-131 shall be that concentration of 1-131 (microcuries/gram) that alone would produce the same Total Effective Dose Equivalent (TEDE) dose as the quantity and isotopic mixture of 1-131, 1-132, 1-133, 1-134. and 1-135 actually present. The dose conversion factors used for this calculation shall be those listed in Federal Guidance Report (FGR) 11, "Limiting Values of (continued)

Columbia Generating Station 1.1-2 Amendment No. 149,169,19G 199

Definitions 1.1 1.1 Definitions (continued)

DOSE EQUIVALENT 1-131 Radionuclide Intake and Air Concentration and (continued) Dose Conversion Factors for Inhalation, Submersion, and Ingestion," 1988.

EMERGENCY CORE COOLING The ECCS RESPONSE TIME shall be that time interval SYSTEM (ECCS) RESPONSE from when the monitored parameter exceeds its ECCS TIME initiation setpoint at the channel sensor until the ECCS equipment is capable of performing its safety function (i.e., the valves travel to their required positions, pump discharge pressures reach their required values, etc.). Times shall include diesel generator starting and sequence loading delays, where applicable. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.

END OF CYCLE The EOC-RPT SYSTEM RESPONSE TIME shall be that RECIRCULATION PUMP TRIP time interval from initial signal generation by (EOC-RPT) SYSTEM RESPONSE the associated turbine throttle valve limit switch TIME or from when the turbine governor valve hydraulic control oil pressure drops below the pressure switch setpoint to complete suppression of the electric arc between the fully open contacts of the recirculation pump circuit breaker. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.

ISOLATION SYSTEM The ISOLATION SYSTEM RESPONSE TIME shall be that RESPONSE TIME time interval from when the monitored parameter exceeds its isolation initiation setpoint at the channel sensor until the isolation valves travel to their required positions. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.

(continued)

Columbia Generating Station 1.1-3 Amendment No. 149,169 199

SLC System 3.1.7 3.1 REACTIVITY CONTROL SYSTEMS 3.1.7 Standby Liquid Control (SLC) System LCO 3.1.7 Two SLC subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3. I ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One SLC subsystem A.1 Restore SLC subsystem 7 days inoperable, to OPERABLE status.

B. Two SLC subsystems B.1 Restore one SLC 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months inoperable, subsystem to OPERABLE status.

C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met.

AND C.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months Columbia Generating Station 3.1.7-1 Amendment No. 149,169 199

SLC System 3.1.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.7.1 Verify available volume of sodium 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months pentaborate solution is > 4587 gallons.

SR 3.1.7.2 Verify temperature of sodium pentaborate 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months solution is within the limits of Figure 3.1.7-1.

SR 3.1.7.3 Verify continuity of explosive charge. 31 days SR 3.1.7.4 Verify the concentration of boron in 31 days solution is within the limits of Figure 3.1.7-1. AND Once within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after water or boron is added to solution AND Once within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after solution temperature is restored within the limits of Figure 3.1.7-1 (continued)

Columbia Generating Station 3.1.7-2 Amendment No. 149,169 199

SLC System 3.1.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.7.5 Verify each SLC subsystem manual and power 31 days operated valve in the flow path that is not locked, sealed, or otherwise secured in position, is in the correct position or can be aligned to the correct position.

SR 3.1.7.6 Verify each pump develops a flow rate In accordance

> 41.2 gpm at a discharge pressure with the

> 1220 psig. Inservice Testing Program SR 3.1.7.7 Verify flow through one SLC subsystem from 24 months on a pump into reactor pressure vessel. STAGGERED TEST BASIS SR 3.1.7.8 Verify all heat traced piping between 24 months storage tank and pump suction valve is unblocked. AND Once within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after solution temperature is restored within the limits of Figure 3.1.7-1 Columbia Generating Station 3.1.7-3 Amendment No. 149.169 199

Primary Containment Isolation Instrumentation 3.3.6.1 Table 3.3.6.1-1 (page 3 of 4)

Primary Containment Isolation Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION C.1 REQUIREMENTS VALUE

4. RWCU System Isolation (continued)

b. Differential 1.2.3 1 F SR 3.3.6.1.2 < 46.5 seconds Flow-Time Delay SR 3.3.6.1.5 SR 3.3.6.1.6 1 F SR 3.3.6.1.1 < 271.7 gpm

c. Blowdown Flow- 1.2.3 High SR 3.3.6.1.2 SR 3.3.6.1.5 SR 3.3.6.1.6 SR 3.3.6.1.7 1 F SR 3.3.6.1.3 < 160°F

d. Heat Exchanger 1.2.3 Room Area SR 3.3.6.1.4 Temperature - High SR 3.3.6.1.6 1.2,3 1 F SR 3.3.6.1.3 < 70°F

e. Heat Exchanger Room Area SR 3.3.6.1.4 Ventilation SR 3.3.6.1.6 Differential Temperature - High 1.2.3 1 per room F SR 3.3.6.1.3 < 1801F

f. Pump Room Area Temperature - High SR 3.3.6.1.4 SR 3.3.6.1.6

g. Pump Room Area 1.2.3 1 per room F SR 3.3.6.1.3 100DF Ventilation SR 3.3.6.1.4 Differential SR 3.3.6.1.6 Temperature - High

h. RWCU/RCIC Line 1.2.3 1 F SR 3.3.6.1.3 < 180*F Routing Area SR 3.3.6.1.4 Temperature- High SR 3.3.6.1.6

i. RWCU Line Routing 1,2.3 1 per room F SR 3.3.6.1.3 Area SR 3.3.6.1.4 Temperature - High SR 3.3.6.1.6 Room 409. 509 <~ 175*F Areas Room 408. 511 <. 180*F Areas J. Reactor Vessel 1.2.3 2 F SR 3.3.6.1.2 > -58 inches Water Level - Low SR 3.3.6.1.4 Low, Level 2 SR 3.3.6.1.6

k. SLC System Initiation 1.2.3 2 (c) I SR 3.3.6.1.6 NA I

1. Manual Initiation 1.2.3 2 G SR 3.3.6.1.6 NA (continued)

(c) SLC System Initiation only inputs Into one of the two trip systems.

Columbia Generating Station 3.3.6.1-7 Amendment No. 149,-9 ,!&+/-l 199

Secondary Containment Isolation Instrumentation 3.3.6.2 Table 3.3.6.2-1 (page 1 of 1)

Secondary Containment Isolation Instrumentation APPLICABLE MODES AND REQUIRED OTHER CHANNELS SPECIFIED PER TRIP SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM REQUIREMENTS VALUE

1. Reactor Vessel Water 1.2.3.(a) 2 (c) SR 3.3.6.2.2 > -58 inches Level - Low Low, Level 2 SR 3.3.6.2.3 SR 3.3.6.2.4

2. Drywell Pressure-High 1.2.3 2 (c) SR 3.3.6.2.2 ( 1.88 psig SR 3.3.6.2.3 SR 3.3.6.2.4

3. Reactor Building Vent 1.2,3. 2 SR 3.3.6.2.1 < 16.0 mR/hr Exhaust Plenum Radiation - High (a) SR SR SR 3.3.6.2.2 3.3.6.2.3 3.3.6.2.4 I

4. Manual Initiation 1.2.3. 4 SR 3.3.6.2.4 NA (a)

I (a)

(b)

During operations with a potential Deleted for draining the reactor vessel.

I (c) Also required to initiate the associated LOCA Time Delay Relay Function pursuant to LCO 3.3.5.1.

Columbia Generating Station 3.3.6.2-4 Amendment No. 149,169,1721 199

CREF System Instrumentation 3.3.7.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. As required by C.1 Declare associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from Required Action A.1 CREF subsystem discovery of and referenced in inoperable, loss of CREF Table 3.3.7.1-1. initiation capability in both trip systems AND C.2 Place channel in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months trip.

D. Required Action and D.1 Place associated CREF I hour associated Completion subsystem in the Time of Condition B or pressurization mode C not met. of operation.

OR 0.2 Declare associated I hour CREF subsystem inoperable.

I Columbia Generating Station 3.3.7.1-2 Amendment No. 149,169 199

CREF System Instrumentation 3.3.7.1 SURVEILLANCE REQUIREMENTS

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

1. Refer to Table 3.3.7.1-1 to determine which SRs apply for each CREF System Function.

2. When a channel is placed in an inoperable status solely for performance of required Surveillances, entry into associated Conditions and Required Actions may be delayed for up to 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months provided the associated Function maintains CREF initiation capability.

I SURVEILLANCE FREQUENCY SR 3.3.7.1.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.3.7.1.2 Perform CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.7.1.3 Perform CHANNEL CALIBRATION. 18 months SR 3.3.7.1.4 Perform LOGIC SYSTEM FUNCTIONAL TEST. 24 months Columbia Generating Station 3.3.7.1-3 Amendment No. 149,169,187z 199

CREF System Instrumentation 3.3.7.1 Table 3.3.7.1-1 (page 1 of 1)

Control Room Emergency Filtration System Instrumentation APPLICABLE CONDITIONS MODES OR REQUIRED REFERENCED OTHER CHANNELS FROM SPECIFIED PER TRIP REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS SYSTEM ACTION A.1 REQUIREMENTS VALUE

1. Reactor Vessel 1,2.3. 2 B SR 3.3.7.1.1 > -58 inches Water Level-Low (a) SR 3.3.7.1.2 Low. Level 2 SR 3.3.7.1.3 SR 3.3.7.1.4

2. Drywell 1.2,3 2 C SR 3.3.7.1.1 < 1.88 psig Pressure -High SR 3.3.7.1.2 SR 3.3.7.1.3 SR 3.3.7.1.4

3. Reactor Building 1.2,3, 2 B SR 3.3.7.1.1 < 16.0 mR/hr SR 3.3.7.1.2 Vent Exhaust Plenum Radiation -High (a)

SR SR 3.3.7.1.3 3.3.7.1.4 I

(a) During operations with a potential for draining the reactor vessel.

I Columbia Generating Station 3.3.7.1-4 Amendment No. 149,169 199

PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.3.6 Verify the isolation time of each MSIV is In accordance

> 3 seconds and < 5 seconds. with the Inservice I

Testing Program SR 3.6.1.3.7 Verify each automatic PCIV actuates to 24 months the isolation position on an actual or simulated isolation signal.

SR 3.6.1.3.8 Verify a representative sample of reactor 24 months instrument line EFCVs actuate to the isolation position on an actual or simulated instrument line break signal.

SR 3.6.1.3.9 Remove and test the explosive squib from 24 months on a each shear isolation valve of the TIP STAGGERED TEST System. BASIS SR 3.6.1.3.10 Verify the combined leakage rate for all In accordance secondary containment bypass leakage with the paths is < 0.04% primary containment Primary volume/day when pressurized to > P,. Containment Leakage Rate I

Testing Program (continued)

I Columbia Generating Station 3.6.1.3-8 Amendment No. 4-S 149,159,170, 199

PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.3.11 Verify leakage rate through each MSIV is In accordance

< 16.0 scfh when tested at > 25.0 psig. with the Primary I

Containment Leakage Rate Testing Program SR 3.6.1.3.12 Verify combined leakage rate through In accordance hydrostatically tested lines that with the penetrate the primary containment is Primary within limits. Containment Leakage Rate Testing Program Columbia Generating Station 3.6.1.3-9 Amendment No. 149,169 199

Secondary Containment 3.6.4.1 3.6 CONTAINMENT SYSTEMS 3.6.4.1 Secondary Containment LCO 3.6.4.1 The secondary containment shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3, During operations with a potential for draining the reactor vessel (OPDRVs).

I ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Secondary containment A.1 Restore secondary 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months inoperable in MODE 1. containment to 2, or 3. OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A AND not met.

B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months C. Secondary containment C.1 Initiate action to Immediately inoperable during suspend OPDRVs.

OPDRVs.

Columbia Generating Station 3.6.4.1-1 Amendment No. 149,169 199

Secondary Containment 3.6.4.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.1.1 Verify secondary containment vacuum is 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months

> 0.25 inch of vacuum water gauge.

SR 3.6.4.1.2 Verify all secondary containment 31 days equipment hatches are closed and sealed.

SR 3.6.4.1.3 Verify each secondary containment access 31 days inner door or each secondary containment access outer door in each access opening is closed.

SR 3.6.4.1.4 Verify each standby gas treatment (SGT) 24 months on a subsystem will draw down the secondary STAGGERED TEST containment to > 0.25 inch of vacuum BASIS water gauge in < 120 seconds.

SR 3.6.4.1.5 Verify each SGT subsystem can maintain 24 months on a

> 0.25 inch of vacuum water gauge in the STAGGERED TEST secondary containment for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months at a BASIS flow rate < 2240 cfm.

Columbia Generating Station 3.6.4.1-2 Amendment No. 149,169 199

SCIVs 3.6.4.2 3.6 CONTAINMENT SYSTEMS 3.6.4.2 Secondary Containment Isolation Valves (SCIVs)

LCO 3.6.4.2 Each SCIV shall be OPERABLE.

APPLICABILITY: MODES 1, 2. and 3, During operations with a potential for draining the reactor vessel (OPDRVs).

I ACTIONS

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

1. Penetration 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 SCIVs.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 Isolate the affected 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months penetration flow paths penetration flow path with one SCIV by use of at least inoperable, one closed and de-activated automatic valve, closed manual valve.

or blind flange.

AND (continued)

Columbia Generating Station 3.6.4.2-1 Amendment No. 149,169 199

SCIVs 3.6.4.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2 ---------NOTE-------

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

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

B.---------- NOTE--------- B.1 Isolate the affected 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Only applicable to penetration flow path penetration flow paths by use of at least with two isolation one closed and valves. de-activated automatic valve, closed manual valve, One or more or blind flange.

penetration flow paths with two SCIVs inoperable.

C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A AND or B not met in MODE 1. 2, or 3. C.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months D. Required Action and D.1 Initiate action to Immediately associated Completion suspend OPDRVs.

Time of Condition A or B not met during OPDRVs.

Columbia Generating Station 3.6.4.2-2 Amendment No. 149,169 199

SCIVs 3.6.4.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.2.1 ------------------- NOTES-----------------

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

2. Not required to be met for SCIVs that are open under administrative controls.

Verify each secondary containment 31 days isolation manual valve and blind flange that is required to be closed during accident conditions is closed.

SR 3.6.4.2.2 Verify the isolation time of each power In accordance operated and each automatic SCIV is with the within limits. Inservice Testing Program SR 3.6.4.2.3 Verify each automatic SCIV actuates to 24 months the isolation position on an actual or simulated automatic isolation signal.

Columbia Generating Station 3.6.4.2-3 Amendment No. 449,469 199

SGT System 3.6.4.3 3.6 CONTAINMENT SYSTEMS 3.6.4.3 Standby Gas Treatment (SGT) System LCO 3.6.4.3 Two SGT subsystems shall be OPERABLE.

APPLICABILITY: MODES 1. 2, and 3.

During operations with a potential vessel (OPDRVs).

for draining the reactor I

ACTIONS CONDITION REOUIRED ACTION COMPLETION TIME A. One SGT subsystem A.1 Restore SGT subsystem 7 days inoperable, to OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A AND not met in MODE 1, 2, or 3. B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months C. Required Action and C.1 Place OPERABLE SGT Immediately associated Completion subsystem in Time of Condition A operation.

not met during OPDRVs. OR C.2 Initiate action to Immediately suspend OPDRVs.

(continued)

Columbia Generating Station 3.6.4.3-1 Amendment No. 149,169 199

SGT System 3.6.4.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. Two SGT subsystems D.1 Enter LCO 3.0.3. Immediately inoperable in MODE 1, 2, or 3.

E. Two SGT subsystems E.1 Initiate action to Immediately inoperable during suspend OPDRVs.

OPDRVs.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.3.1 Operate each SGT subsystem for 31 days

> 10 continuous hours with heaters operating.

SR 3.6.4.3.2 Perform required SGT filter testing in In accordance accordance with the Ventilation Filter with the VFTP Testing Program (VFTP).

SR 3.6.4.3.3 Verify each SGT subsystem actuates on an 24 months actual or simulated initiation signal.

SR 3.6.4.3.4 Verify each SGT filter cooling 24 months recirculation valve can be opened and the fan started.

Columbia Generating Station 3.6.4.3-2 Amendment No. 149,169 199

CREF System 3.7.3 3.7 PLANT SYSTEMS 3.7.3 Control Room Emergency Filtration (CREF) System LCO 3.7.3 Two CREF subsystems shall be OPERABLE.

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

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

APPLICABILITY: MODES 1, 2, and 3.

During operations with a potential vessel (OPDRVs).

for draining the reactor I

ACTIONS CONDITION REOUIRED ACTION COMPLETION TIME A. One CREF subsystem A.1 Restore CREF 7 days inoperable, subsystem to OPERABLE status.

B. Two CREF subsystems B.1 Restore control room 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months inoperable due to boundary to OPERABLE inoperable control status.

room boundary in MODES 1, 2, and 3.

C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Associated Completion Time of Condition A or AND B not met in MODE 1, 2, or 3. C.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (continued)

Columbia Generating Station 3.7.3-1 Amendment No. 149,16-9,18 199

CREF System 3.7.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Place OPERABLE CREF Immediately associated Completion subsystem in Time of Condition A pressurization mode.

not met during OPDRVs. OR D.2 Initiate action to Immediately suspend OPDRVs.

E. Two CREF subsystems E.1 Enter LCO 3.0.3. Immediately inoperable in MODE 1,

2. or 3 for reasons other than Condition B.

F. Two CREF subsystems F.1 Initiate action to Immediately inoperable during suspend OPDRVs.

OPDRVs.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.3.1 Operate each CREF subsystem for > 10 31 days continuous hours with the heaters operating.

SR 3.7.3.2 Perform required CREF filter testing in In accordance accordance with the Ventilation Filter with the VFTP Testing Program (VFTP).

(continued)

Columbia Generating Station 3.7.3-2 Amendment No. 149,1}6-9,18& 199

CREF System 3.7.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREOUENCY SR 3.7.3.3 Verify each CREF subsystem actuates on an 24 months actual or simulated initiation signal.

SR 3.7.3.4 Verify each CREF subsystem can maintain a 24 months on a positive pressure of > 1/8 inches water STAGGERED TEST gauge relative to the radwaste and turbine BASIS buildings during the pressurization mode of operation at an outside air flow rate of

< i000 cfm.

Columbia Generating Station 3.7.3-3 Amendment No. 149 169 199

Control Room AC System 3.7.4 3.7 PLANT SYSTEMS 3.7.4 Control Room Air Conditioning (AC) System LCO 3.7.4 Two control room AC subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2. and 3, During operations with a potential vessel (OPDRVs).

for draining the reactor I

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One control room AC A.1 Restore control room 30 days subsystem inoperable. AC subsystem to OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Associated Completion Time of Condition A AND not met in MODE 1, 2, or 3. B.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months C. Required Action and C.1 Place OPERABLE Immediately associated Completion control room AC Time of Condition A subsystem in not met during operation.

OPDRVs.

OR C.2 Initiate action to Immediately suspend OPDRVs.

(continued)

Columbia Generating Station 3.7.4-1 Amendment No. 149,169 199

Control Room AC System 3.7.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME D. Two control room AC D.1 Enter LCO 3.0.3. Immediately subsystems inoperable in MODE 1, 2. or 3.

E. Two control room AC E.1 Initiate action to Immediately subsystems inoperable suspend OPDRVs.

during OPDRVs.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.1 Verify each control room AC subsystem has 24 months the capability to remove the assumed heat load.

Columbia Generating Station 3.7.4-2 Amendment No. 149,169 199

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 qualified circuit between the offsite transmission network and the onsite Class I E AC electrical power distribution subsystem9sO required by LCO 3.8.8, "Distribution Systems - Shutdown;"

b. One diesel generator (DG) capable of supplying one division of the Division I or 2 onsite Class 1E AC electrical power distribution subsystem(s) required by LCO 3.8.8; and

c. The Division 3 DG capable of supplying the Division 3 onsite Class IE AC electrical power distribution subsystem, when the-Division 3 onsite Class IE electrical power distribution subsystem is required by LCO 3.8.8.

APPLICABILITY: MODES 4 and 5.

Columbia Generating Station 3.8.2-1 Amendment No. 149,169 199

AC Sources - Shutdown 3.8.2 ACTIONS I

CONDITION REQUIRED ACTION COMPLETION TIME A. Required offsite -------------- NOTE----------

circuit inoperable. Enter applicable Condition and Required Actions of LCO 3.8.8, when any required division is de-energized as a result of Condition A.

A.1 Declare affected Immediately required feature(s) with no offsite power available inoperable.

OR A.2.1 Initiate action to suspend operations Immediately I

with a potential for draining the reactor vessel (OPDRVs).

AND A.2.2 Initiate action to restore required Immediately I

offsite power circuit to OPERABLE status.

B. Division 1 or 2 required DG B.1 Initiate action to suspend OPDRVs.

Immediately I

inoperable.

AND B.2 Initiate action to restore required DG Immediately I

to OPERABLE status.

(continued)

Columbia Generating Station 3.8.2-2 Amendment No. 149,169 199

AC Sources - Shutdown 3.8.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. Required Division 3 DG C.1 Declare High Pressure 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable. Core Spray System inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.2.1 ------------------- NOTE------------------

The following SRs are not required to be performed: SR 3.8.1.3, SR 3.8.1.9 through SR 2.8.1.11, SR 3.8.1.13 through SR 3.8.1.16, SR 3.8.1.18, and SR 3.8.1.19.

For AC sources required to be OPERABLE, In accordance the SRs for Specification 3.8.1 except SR with applicable 3.8.1.8, SR 3.8.1.17, and SR 3.8.1.20, SRs are applicable Columbia Generating Station 3.8.2-3 Amendment No. 149.169 199

DC Sources- Shutdown 3.8.5 3.8 ELECTRICAL POWER SYSTEMS 3.8.5 DC Sources-Shutdown LCO 3.8.5 DC electrical power subsystem(s) shall be OPERABLE to support the electrical power distribution subsystem(s) required by LCO 3.8.8, "Distribution Systems-Shutdown."

APPLICABILITY: MODES 4 and 5.

I I

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Declare affected Immediately DC electrical power required feature(s) subsystems inoperable, inoperable.

OR A.2.1 Initiate action to Immediately suspend operations with a potential for draining the reactor vessel.

AND A.2.2 Initiate action to Immediately restore required DC electrical power subsystems to OPERABLE status.

Columbia Generating Station 3.8.5-1 Amendment No. 149,169 199

DC Sources- Shutdown 3.8.5 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.8.5.1 ------ ------------------

NOTE------

The following SRs are not required to be performed: SR 3.8.4.6, SR 3.8.4.7, and SR 3.8.4.8.

For DC electrical power subsystems required In accordance to be OPERABLE the following SRs are with applicable applicable: SRs SR 3.8.4.1, SR 3.8.4.2, SR 3.8.4.3, SR 3.8.4.4, SR 3.8.4.5, SR 3.8.4.6, SR 3.8.4.7, and SR 3.8.4.8.

Columbia Generating Station 3.8.5-2 Amendment No. 149,169 199

Distribution Systems -Shutdown 3.8.8 3.8 ELECTRICAL POWER SYSTEMS 3.8.8 Distribution Systems-Shutdown LCO 3.8.8 The necessary portions of the Division 1. Division 2. and Division 3 AC and DC electrical power distribution subsystems shall be OPERABLE to support equipment required to be OPERABLE.

APPLICABILITY: MODES 4 and 5.

I I

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Declare associated Immediately AC or DC electrical supported required power distribution feature(s) subsystems inoperable, inoperable.

OR A.2.1 Initiate action to suspend operations Immediately I

with a potential for draining the reactor vessel.

AND A.2.2 Initiate actions to restore required AC Immediately I

and DC electrical power distribution subsystems to OPERABLE status.

AND (continued)

Columbia Generating Station 3.8.8-1 Amendment No. 149.169 199

Distribution Systems- Shutdown 3.8.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.3 Declare associated required shutdown Immediately I

cooling subsystem(s) inoperable and not in operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.8.1 Verify correct breaker alignments and 7 days indicated power availability to required AC and DC electrical power distribution subsystems.

Columbia Generating Station 3.8.8-2 Amendment No. 149,169 199

RPV Water Level-New Fuel or Control Rods 3.9.7 3.9 REFUELING OPERATIONS 3.9.7 Reactor Pressure Vessel (RPV) Water Level-New Fuel or Control Rods LCO 3.9.7 RPV water level shall be > 23 ft above the top of irradiated fuel assemblies seated within the RPV.

I APPLICABILITY: During movement of new fuel assemblies or handling of control rods within the RPV when irradiated fuel assemblies are seated within the RPV.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RPV water level not A.1 Suspend movement of Immediately within limit, new fuel assemblies and handling of control rods within the RPV.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.7.1 Verify RPV water level is > 23 ft above the top of irradiated fuel assemblies seated 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months I

within the RPV.

Columbia Generating Station 3.9.7-1 Amendment No. 149,169 199

Decay Time 3.9.10 3.9 REFUELING OPERATIONS 3.9.10 Decay Time LCO 3.9.10 The reactor shall be subcritical for at least 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

APPLICABILITY: During in-vessel fuel movement.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. With the reactor A.1 Suspend in-vessel Immediately subcritical for less fuel movement.

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

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.10.1 Verify the rector has been subcritical for Once prior to at least 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . the movement of irradiated fuel in the reactor vessel.

Columbia Generating Station 3.9.10-1 Amendment No. 199 1

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.7 Ventilation Filter Testing Program (VFTP) (continued)

ESF Ventilation System Flowrate (cfm)

SGT System 4320 to 5280 CREF System 900 to 1100

b. Demonstrate for each of the ESF systems that an inplace test of the charcoal adsorber shows a penetration and system bypass < 0.05% when tested in accordance with Regulatory Guide 1.52, Revision 2, and ASME N510-1989 at the system flowrate specified below:

ESF Ventilation System Flowrate (cfm)

SGT System CREF System 4320 to 5280 900 to 1100 I

c. Demonstrate for each of the ESF systems that 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 the value specified below when tested in accordance with ASTM D3803-1989 at a temperature of 30 0 C (86 0 F) and the relative humidity specified below. Testing of the SGT System will also be conducted at a face velocity of 75 feet per minute.

ESF Ventilation System Penetration (M) RH (M)

SGT System 0.5 70 CREF System 2.5 70 Allowed tolerances in the above testing parameters of temperature, relative humidity, and face velocity are as specified in ASTM D3803-1989.

d. Demonstrate for each of the ESF systems that the pressure drop across the combined HEPA filters and the charcoal adsorbers is less than the value specified below when tested at the system flowrate specified below:

ESF Ventilation System Delta P Flowrate (inches wg) (cfm)

SGT System CREF System

<8

<6 4320 to 5280 900 to 1100 I

(continued)

Columbia Generating Station 5.5-7 Amendment No. 149,169,18t2 199

v t e Letter Sequence Other
TAC:MC4570, Revise Containment Requirements During Handling Irradiated Fuel and Core Alterations (Approved, Closed)
Initiation Request, Request, Request Acceptance Administration Meeting, Meeting Questions 9 February 2006 11 July 2006 9 August 2006 Answers 21 March 2006 24 August 2006 29 September 2005 Results Approval, Approval, Approval Other: GO2-07-021, License Amendment 199 Safety Evaluation Corrections, ML052620418, ML063280053, ML070160169
MONTHYEAR2006-07-11 [Table View]

ML063280053

Text

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