GO2-17-124, Final Technical Specification Markup and Clean Pages for Application to Revise Technical Specifications to Adopt TSTF-545, Revision 3

Final Technical Specification Markup and Clean Pages for Application to Revise Technical Specifications to Adopt TSTF-545, Revision 3

ML17186A435
Person / Time
Site:	Columbia
Issue date:	07/05/2017
From:	Javorik A Energy Northwest
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
GO2-17-124
Download: ML17186A435 (30)

Text

Alex L. Javorik Vice President, Engineering P.O. Box 968, Mail Drop PE04 Richland, WA 99352-0968 Ph. 509-377-8555 F. 509-377-2354 aljavorik@energy-northwest.com 10 CFR 50.90 10 CFR 50.55a July 5, 2017 GO2-17-124 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001

SUBJECT:

COLUMBIA GENERATING STATION, DOCKET NO. 50-397 FINAL TECHNICAL SPECIFICATION MARKUP AND CLEAN PAGES FOR APPLICATION TO REVISE TECHNICAL SPECIFICATIONS TO ADOPT TSTF-545, REVISION 3

Reference:

Letter A.L. Javorik, Energy Northwest to NRC, Application To Revise Technical Specifications To Adopt TSTF-545, Revision 3, GO2-16-076, (ADAMS Accession No. ML16196A419), Dated July 14, 2016.

Dear Sir or Madam:

By the referenced letter, Energy Northwest submitted for approval the License Amendment Request (LAR) to adopt TSTF-545, Revision 3.

This letter transmits the final markup and clean pages of the Technical Specifications (TS) for the LAR referenced above. This final set of markup and clean TS pages supersedes all other previously submitted markup and clean TS pages for this LAR. Attachment 1 contains the markup pages of the TS. contains the clean pages of the TS.

All TS pages made obsolete by implementation of License Amendment 226 remain retained in the Columbia TS. These obsolete pages will be deleted under a separate LAR with a projected submission date of November 30, 2017.

The No Significant Hazards Consideration Determination (NSHCD) provided in the original submittal is not altered by this submittal. This letter and its attachment contain no regulatory commitments.

If you should have any questions regarding this submittal, please contact Ms. L. L.

Williams, Licensing Supervisor, at 509-377-8148.

G02-17-124 Page 2 of 2 I declare under penalty of perjury that the foregoing is true and correct.

Executed on this 5 ~/,_ day of ~0 , 2017.

Respectfully, A. L. Jav nk Vice President, Engineering Attachments: As stated cc: NRC Region IV Administrator NRC NRR Project Manager NRC Sr. Resident Inspector - 988C CD Sonoda - BPA - 1399 (w/o enclosures)

WA Horin - Winston & Strawn (email)

RR Cowley-WDOH (email)

EFSECutc.wa.gov-- EFSEC (email)

GO2-17-124 TECHNICAL SPECIFICATIONS CHANGES (MARK-UPS)

Definitions 1.1 1.1 Definitions END OF CYCLE The EOC-RPT SYSTEM RESPONSE TIME shall be that time RECIRCULATION PUMP interval from initial signal generation by the associated turbine TRIP (EOC-RPT) SYSTEM throttle valve limit switch or from when the turbine governor RESPONSE TIME 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.

INSERVICE TESTING The INSERVICE TESTING PROGRAM is the licensee PROGRAM program that fulfills the requirements of 10 CFR 50.55a(f).

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.

LEAKAGE LEAKAGE shall be:

a. Identified LEAKAGE

1. LEAKAGE into the drywell such as that from pump seals or valve packing, that is captured and conducted to a sump or collecting tank; or

2. LEAKAGE into the drywell atmosphere from sources that are both specifically located and known either not to interfere with the operation of leakage detection systems or not to be pressure boundary LEAKAGE;

b. Unidentified LEAKAGE All LEAKAGE into the drywell that is not identified LEAKAGE;

c. Total LEAKAGE Sum of the identified and unidentified LEAKAGE; and

d. Pressure Boundary LEAKAGE LEAKAGE through a nonisolable fault in a Reactor Coolant System (RCS) component body, pipe wall, or vessel wall.

Columbia Generating Station 1.1-3 Amendment No. 149,169 225

SLC System 3.1.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.7.6 Verify each pump develops a flow rate 41.2 gpm In accordance at a discharge pressure 1220 psig. with the Inservice Testing Program INSERVICE TESTING PROGRAM SR 3.1.7.7 Verify flow through one SLC subsystem from pump In accordance into reactor pressure vessel. with the Surveillance Frequency Control Program SR 3.1.7.8 Verify all heat traced piping between storage tank In accordance and pump suction valve is unblocked. with the Surveillance Frequency Control Program AND Once within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after solution temperature is restored within the limits of Figure 3.1.7-1 SR 3.1.7.9 Verify sodium pentaborate enrichment is 44.0 Prior to addition to atom percent B-10. SLC Tank Columbia Generating Station 3.1.7-3 Amendment No. 199,221 225 238

SRVs - 25% RTP 3.4.3 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.3 Safety/Relief Valves (SRVs) - 25% RTP LCO 3.4.3 The safety function of 12 SRVs shall be OPERABLE, with two SRVs in the lowest two lift setpoint groups OPERABLE.

APPLICABILITY: THERMAL POWER 25% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Reduce THERMAL 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> SRVs inoperable. POWER to < 25% RTP.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.3.1 Verify the safety function lift setpoints of the required In accordance SRVs are as follows: with the Inservice Testing Program Number of Setpoint INSERVICE SRVs (psig) TESTING PROGRAM 2 1165 + 34.9

- 58.2 4 1175 + 35.2

- 58.7 4 1185 + 35.5

- 59.2 4 1195 + 35.8

- 59.7 4 1205 +/- 36.1

- 60.2 Following testing, lift settings shall be within +3%.

Columbia Generating Station 3.4.3-1 Amendment No. 149,169 225 238, 240

SRVs - < 25% RTP 3.4.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.4.1 Verify the safety function lift setpoints of the required In accordance SRVs are as follows: with the Inservice Testing Program Number of Setpoint INSERVICE SRVs (psig) TESTING PROGRAM 2 1165 + 34.9

- 58.2 4 1175 + 35.2

- 58.7 4 1185 + 35.5

- 59.2 4 1195 + 35.8

- 59.7 4 1205 +/- 36.1

- 60.2 Following testing, lift settings shall be within +3%.

SR 3.4.4.2 -------------------------------NOTE------------------------------

Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after reactor steam pressure and flow are adequate to perform the test.

Verify each required SRV opens when manually In accordance actuated. with the Surveillance Frequency Control Program Columbia Generating Station 3.4.4-2 Amendment No. 149,169,225,236,238,240

RCS PIV Leakage 3.4.6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met. AND B.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.6.1 -------------------------------NOTE------------------------------

Only required to be performed in MODES 1 and 2.

Verify equivalent leakage of each RCS PIV is In accordance 0.5 gpm per nominal inch of valve size up to a withInservice maximum of 5 gpm, at an RCS pressure of Testing Program 1035 psig. The actual test pressure shall be the INSERVICE 935 psig. TESTING PROGRAM Columbia Generating Station 3.4.6-2 Amendment No. 149,169 225

ECCS - Operating 3.5.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.1 Verify, for each ECCS injection/spray subsystem, In accordance the piping is filled with water from the pump with the discharge valve to the injection valve. Surveillance Frequency Control Program SR 3.5.1.2 ------------------------------NOTE-------------------------------

Low pressure coolant injection (LPCI) subsystems may be considered OPERABLE during alignment and operation for decay heat removal with reactor steam dome pressure less than 48 psig in MODE 3, if capable of being manually realigned and not otherwise inoperable.

Verify each ECCS injection/spray subsystem In accordance manual, power operated, and automatic valve in the with the flow path, that is not locked, sealed, or otherwise Surveillance secured in position, is in the correct position. Frequency Control Program SR 3.5.1.3 Verify ADS accumulator backup compressed gas In accordance system average pressure in the required bottles is with the 2200 psig. Surveillance Frequency Control Program SR 3.5.1.4 Verify each ECCS pump develops the specified flow In accordance rate with the specified differential pressure between with the Inservice reactor and suction source. Testing Program INSERVICE DIFFERENTIAL TESTING PRESSURE PROGRAM BETWEEN REACTOR AND SYSTEM FLOW RATE SUCTION SOURCE LPCS 6200 gpm 128 psid LPCI 7200 gpm 26 psid HPCS 6350 gpm 200 psid Columbia Generating Station 3.5.1-4 Amendment No. 169,205,225,229,236 238

ECCS - Shutdown 3.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.3 Verify, for each required ECCS injection/spray In accordance subsystem, the piping is filled with water from the with the pump discharge valve to the injection valve. Surveillance Frequency Control Program SR 3.5.2.4 ------------------------------NOTE-------------------------------

One low pressure coolant injection (LPCI) subsystem may be considered OPERABLE during alignment and operation for decay heat removal, if capable of being manually realigned and not otherwise inoperable.

Verify each required ECCS injection/spray In accordance subsystem manual, power operated, and automatic with the valve in the flow path, that is not locked, sealed, or Surveillance otherwise secured in position, is in the correct Frequency position. Control Program SR 3.5.2.5 Verify each required ECCS pump develops the In accordance specified flow rate with the specified differential with the Inservice pressure between reactor and suction source. Testing Program INSERVICE DIFFERENTIAL TESTING PRESSURE PROGRAM BETWEEN REACTOR AND SYSTEM FLOW RATE SUCTION SOURCE LPCS 6200 gpm 128 psid LPCI 7200 gpm 26 psid HPCS 6350 gpm 200 psid Columbia Generating Station 3.5.2-3 Amendment No. 169,205 225 229 238

PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.3.3 ------------------------------NOTES-----------------------------

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

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

Verify each primary containment isolation manual Prior to entering valve and blind flange that is located inside primary MODE 2 or 3 from containment and not locked, sealed, or otherwise MODE 4 if secured and is required to be closed during accident primary conditions is closed. containment was de-inerted while in MODE 4, if not performed within the previous 92 days SR 3.6.1.3.4 Verify continuity of the traversing incore probe (TIP) In accordance shear isolation valve explosive charge. with the Surveillance Frequency Control Program SR 3.6.1.3.5 Verify the isolation time of each power operated, In accordance automatic PCIV, except for MSIVs, is within limits. with the Inservice Testing Program INSERVICE TESTING PROGRAM SR 3.6.1.3.6 Verify the isolation time of each MSIV is In accordance 3 seconds and 5 seconds. with the Inservice Testing Program INSERVICE TESTING PROGRAM Columbia Generating Station 3.6.1.3-7 Amendment No. 199,208 225 238

PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.3.7 Verify each automatic PCIV actuates to the isolation In accordance position on an actual or simulated isolation signal. with the Surveillance Frequency Control Program SR 3.6.1.3.8 Verify a representative sample of reactor instrument In accordance line EFCVs actuate to the isolation position on an with the actual or simulated instrument line break signal. Surveillance Frequency Control Program SR 3.6.1.3.9 Remove and test the explosive squib from each In accordance shear isolation valve of the TIP System. with the Surveillance Frequency Control Program SR 3.6.1.3.10 Verify the combined leakage rate for all secondary In accordance containment bypass leakage paths is 0.04% with the Primary primary containment volume/day when pressurized Containment to Pa. Leakage Rate Testing Program 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 Containment Leakage Rate Testing Program SR 3.6.1.3.12 Verify combined leakage rate through hydrostatically In accordance tested lines that penetrate the primary containment with the Primary is within limits. Containment Leakage Rate Testing Program Columbia Generating Station 3.6.1.3-8 Amendment No. 199,208 225 238

Reactor Building-to-Suppression Chamber Vacuum Breakers 3.6.1.6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME E. Two or more lines with E.1 Restore all vacuum 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> one or more reactor breakers in two lines to building-to-suppression OPERABLE status.

chamber vacuum breakers inoperable for opening.

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

F.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.6.1 ------------------------------NOTES-----------------------------

1. Not required to be met for vacuum breakers that are open during Surveillances.

2. Not required to be met for vacuum breakers open when performing their intended function.

Verify each vacuum breaker is closed. In accordance with the Surveillance Frequency Control Program SR 3.6.1.6.2 Perform a functional test of each vacuum breaker. In accordance with the Inservice Testing Program INSERVICE TESTING PROGRAM Columbia Generating Station 3.6.1.6-2 Amendment No. 149,169,225,236 238

RHR Suppression Pool Cooling 3.6.2.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.3.1 Verify each RHR suppression pool cooling In accordance subsystem manual, power operated, and automatic with the valve in the flow path that is not locked, sealed, or Surveillance otherwise secured in position, is in the correct Frequency position or can be aligned to the correct position. Control Program SR 3.6.2.3.2 Verify each RHR pump develops a flow rate In accordance 7100 gpm through the associated heat exchanger with the Inservice while operating in the suppression pool cooling Testing Program mode. INSERVICE TESTING PROGRAM Columbia Generating Station 3.6.2.3-2 Amendment No. 169 225 230 238

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 isolation manual In accordance valve and blind flange that is not locked, sealed, or with the otherwise secured, and is required to be closed Surveillance during accident conditions is closed. Frequency Control Program SR 3.6.4.2.2 Verify the isolation time of each power operated, In accordance automatic SCIV is within limits. with the Inservice Testing Program INSERVICE TESTING PROGRAM SR 3.6.4.2.3 Verify each automatic SCIV actuates to the isolation In accordance position on an actual or simulated automatic with the isolation signal. Surveillance Frequency Control Program Columbia Generating Station 3.6.4.2-3 Amendment No. 208 225 238

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.5 Component Cyclic or Transient Limit This program provides controls to track the FSAR, Table 3.9-1, Note 1, cyclic and transient occurrences to ensure that components are maintained within the design limits.

5.5.6 DeletedInservice Testing Program This program provides controls for inservice testing of ASME Code Class 1, 2, and 3 pumps and valves.

a. Testing Frequencies applicable to the ASME Code for Operations and Maintenance of Nuclear Power Plants (ASME OM Code) and applicable Addenda as follows:

ASME OM Code and applicable Required Frequencies for Addenda performing terminology for inservice inservice testing testing activities activities Weekly At least once per 7 days Monthly At least once per 31 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 and to other normal and accelerated Frequencies specified as 2 years or less in the Inservice Testing Program 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 OM Code shall be construed to supersede the requirements of any TS.

Columbia Generating Station 5.5-4 Amendment 182,205 225

GO2-17-124 TECHNICAL SPECIFICATIONS CLEAN PAGES

Definitions 1.1 1.1 Definitions END OF CYCLE The EOC-RPT SYSTEM RESPONSE TIME shall be that time RECIRCULATION PUMP interval from initial signal generation by the associated turbine TRIP (EOC-RPT) SYSTEM throttle valve limit switch or from when the turbine governor RESPONSE TIME 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.

INSERVICE TESTING The INSERVICE TESTING PROGRAM is the licensee PROGRAM program that fulfills the requirements of 10 CFR 50.55a(f).

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.

LEAKAGE LEAKAGE shall be:

a. Identified LEAKAGE

1. LEAKAGE into the drywell such as that from pump seals or valve packing, that is captured and conducted to a sump or collecting tank; or

2. LEAKAGE into the drywell atmosphere from sources that are both specifically located and known either not to interfere with the operation of leakage detection systems or not to be pressure boundary LEAKAGE;

b. Unidentified LEAKAGE All LEAKAGE into the drywell that is not identified LEAKAGE;

c. Total LEAKAGE Sum of the identified and unidentified LEAKAGE; and

d. Pressure Boundary LEAKAGE LEAKAGE through a nonisolable fault in a Reactor Coolant System (RCS) component body, pipe wall, or vessel wall.

Columbia Generating Station 1.1-3 Amendment No. 149,169 225

SLC System 3.1.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.7.6 Verify each pump develops a flow rate 41.2 gpm In accordance at a discharge pressure 1220 psig. with the INSERVICE TESTING PROGRAM SR 3.1.7.7 Verify flow through one SLC subsystem from pump In accordance into reactor pressure vessel. with the Surveillance Frequency Control Program SR 3.1.7.8 Verify all heat traced piping between storage tank In accordance and pump suction valve is unblocked. with the Surveillance Frequency Control Program AND Once within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after solution temperature is restored within the limits of Figure 3.1.7-1 SR 3.1.7.9 Verify sodium pentaborate enrichment is 44.0 Prior to addition to atom percent B-10. SLC Tank Columbia Generating Station 3.1.7-3 Amendment No. 199,221 225 238

SRVs - 25% RTP 3.4.3 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.3 Safety/Relief Valves (SRVs) - 25% RTP LCO 3.4.3 The safety function of 12 SRVs shall be OPERABLE, with two SRVs in the lowest two lift setpoint groups OPERABLE.

APPLICABILITY: THERMAL POWER 25% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Reduce THERMAL 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> SRVs inoperable. POWER to < 25% RTP.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.3.1 Verify the safety function lift setpoints of the required In accordance SRVs are as follows: with the INSERVICE Number of Setpoint TESTING SRVs (psig) PROGRAM 2 1165 + 34.9

- 58.2 4 1175 + 35.2

- 58.7 4 1185 + 35.5

- 59.2 4 1195 + 35.8

- 59.7 4 1205 +/- 36.1

- 60.2 Following testing, lift settings shall be within +3%.

Columbia Generating Station 3.4.3-1 Amendment No. 149,169 225 238, 240

SRVs - < 25% RTP 3.4.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.4.1 Verify the safety function lift setpoints of the required In accordance SRVs are as follows: with the INSERVICE Number of Setpoint TESTING SRVs (psig) PROGRAM 2 1165 + 34.9

- 58.2 4 1175 + 35.2

- 58.7 4 1185 + 35.5

- 59.2 4 1195 + 35.8

- 59.7 4 1205 +/- 36.1

- 60.2 Following testing, lift settings shall be within +3%.

SR 3.4.4.2 -------------------------------NOTE------------------------------

Not required to be performed until 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after reactor steam pressure and flow are adequate to perform the test.

Verify each required SRV opens when manually In accordance actuated. with the Surveillance Frequency Control Program Columbia Generating Station 3.4.4-2 Amendment No. 149,169,225,236,238,240

RCS PIV Leakage 3.4.6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met. AND B.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.6.1 -------------------------------NOTE------------------------------

Only required to be performed in MODES 1 and 2.

Verify equivalent leakage of each RCS PIV is In accordance 0.5 gpm per nominal inch of valve size up to a with the maximum of 5 gpm, at an RCS pressure of INSERVICE 1035 psig. The actual test pressure shall be TESTING 935 psig. PROGRAM Columbia Generating Station 3.4.6-2 Amendment No. 149,169 225

ECCS - Operating 3.5.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.1 Verify, for each ECCS injection/spray subsystem, In accordance the piping is filled with water from the pump with the discharge valve to the injection valve. Surveillance Frequency Control Program SR 3.5.1.2 ------------------------------NOTE-------------------------------

Low pressure coolant injection (LPCI) subsystems may be considered OPERABLE during alignment and operation for decay heat removal with reactor steam dome pressure less than 48 psig in MODE 3, if capable of being manually realigned and not otherwise inoperable.

Verify each ECCS injection/spray subsystem In accordance manual, power operated, and automatic valve in the with the flow path, that is not locked, sealed, or otherwise Surveillance secured in position, is in the correct position. Frequency Control Program SR 3.5.1.3 Verify ADS accumulator backup compressed gas In accordance system average pressure in the required bottles is with the 2200 psig. Surveillance Frequency Control Program SR 3.5.1.4 Verify each ECCS pump develops the specified flow In accordance rate with the specified differential pressure between with the reactor and suction source. INSERVICE TESTING DIFFERENTIAL PROGRAM PRESSURE BETWEEN REACTOR AND SYSTEM FLOW RATE SUCTION SOURCE LPCS 6200 gpm 128 psid LPCI 7200 gpm 26 psid HPCS 6350 gpm 200 psid Columbia Generating Station 3.5.1-4 Amendment No. 169,205,225,229,236 238

ECCS - Shutdown 3.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.3 Verify, for each required ECCS injection/spray In accordance subsystem, the piping is filled with water from the with the pump discharge valve to the injection valve. Surveillance Frequency Control Program SR 3.5.2.4 ------------------------------NOTE-------------------------------

One low pressure coolant injection (LPCI) subsystem may be considered OPERABLE during alignment and operation for decay heat removal, if capable of being manually realigned and not otherwise inoperable.

Verify each required ECCS injection/spray In accordance subsystem manual, power operated, and automatic with the valve in the flow path, that is not locked, sealed, or Surveillance otherwise secured in position, is in the correct Frequency position. Control Program SR 3.5.2.5 Verify each required ECCS pump develops the In accordance specified flow rate with the specified differential with the pressure between reactor and suction source. INSERVICE TESTING DIFFERENTIAL PROGRAM PRESSURE BETWEEN REACTOR AND SYSTEM FLOW RATE SUCTION SOURCE LPCS 6200 gpm 128 psid LPCI 7200 gpm 26 psid HPCS 6350 gpm 200 psid Columbia Generating Station 3.5.2-3 Amendment No. 169,205 225 229 238

PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.3.3 ------------------------------NOTES-----------------------------

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

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

Verify each primary containment isolation manual Prior to entering valve and blind flange that is located inside primary MODE 2 or 3 from containment and not locked, sealed, or otherwise MODE 4 if secured and is required to be closed during accident primary conditions is closed. containment was de-inerted while in MODE 4, if not performed within the previous 92 days SR 3.6.1.3.4 Verify continuity of the traversing incore probe (TIP) In accordance shear isolation valve explosive charge. with the Surveillance Frequency Control Program SR 3.6.1.3.5 Verify the isolation time of each power operated, In accordance automatic PCIV, except for MSIVs, is within limits. with the INSERVICE TESTING PROGRAM SR 3.6.1.3.6 Verify the isolation time of each MSIV is In accordance 3 seconds and 5 seconds. with the INSERVICE TESTING PROGRAM Columbia Generating Station 3.6.1.3-7 Amendment No. 199,208 225 238

PCIVs 3.6.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.3.7 Verify each automatic PCIV actuates to the isolation In accordance position on an actual or simulated isolation signal. with the Surveillance Frequency Control Program SR 3.6.1.3.8 Verify a representative sample of reactor instrument In accordance line EFCVs actuate to the isolation position on an with the actual or simulated instrument line break signal. Surveillance Frequency Control Program SR 3.6.1.3.9 Remove and test the explosive squib from each In accordance shear isolation valve of the TIP System. with the Surveillance Frequency Control Program SR 3.6.1.3.10 Verify the combined leakage rate for all secondary In accordance containment bypass leakage paths is 0.04% with the Primary primary containment volume/day when pressurized Containment to Pa. Leakage Rate Testing Program 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 Containment Leakage Rate Testing Program SR 3.6.1.3.12 Verify combined leakage rate through hydrostatically In accordance tested lines that penetrate the primary containment with the Primary is within limits. Containment Leakage Rate Testing Program Columbia Generating Station 3.6.1.3-8 Amendment No. 199,208 225 238

Reactor Building-to-Suppression Chamber Vacuum Breakers 3.6.1.6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME E. Two or more lines with E.1 Restore all vacuum 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> one or more reactor breakers in two lines to building-to-suppression OPERABLE status.

chamber vacuum breakers inoperable for opening.

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

F.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.6.1 ------------------------------NOTES-----------------------------

1. Not required to be met for vacuum breakers that are open during Surveillances.

2. Not required to be met for vacuum breakers open when performing their intended function.

Verify each vacuum breaker is closed. In accordance with the Surveillance Frequency Control Program SR 3.6.1.6.2 Perform a functional test of each vacuum breaker. In accordance with the INSERVICE TESTING PROGRAM Columbia Generating Station 3.6.1.6-2 Amendment No. 149,169,225,236 238

RHR Suppression Pool Cooling 3.6.2.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.3.1 Verify each RHR suppression pool cooling In accordance subsystem manual, power operated, and automatic with the valve in the flow path that is not locked, sealed, or Surveillance otherwise secured in position, is in the correct Frequency position or can be aligned to the correct position. Control Program SR 3.6.2.3.2 Verify each RHR pump develops a flow rate In accordance 7100 gpm through the associated heat exchanger with the while operating in the suppression pool cooling INSERVICE mode. TESTING PROGRAM Columbia Generating Station 3.6.2.3-2 Amendment No. 169 225 230 238

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 isolation manual In accordance valve and blind flange that is not locked, sealed, or with the otherwise secured, and is required to be closed Surveillance during accident conditions is closed. Frequency Control Program SR 3.6.4.2.2 Verify the isolation time of each power operated, In accordance automatic SCIV is within limits. with the INSERVICE TESTING PROGRAM SR 3.6.4.2.3 Verify each automatic SCIV actuates to the isolation In accordance position on an actual or simulated automatic with the isolation signal. Surveillance Frequency Control Program Columbia Generating Station 3.6.4.2-3 Amendment No. 208 225 238

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.5 Component Cyclic or Transient Limit This program provides controls to track the FSAR, Table 3.9-1, Note 1, cyclic and transient occurrences to ensure that components are maintained within the design limits.

5.5.6 Deleted Columbia Generating Station 5.5-4 Amendment 182,205 225