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

{{Adams
| number = ML17186A435
| issue date = 07/05/2017
| title = Final Technical Specification Markup and Clean Pages for Application to Revise Technical Specifications to Adopt TSTF-545, Revision 3
| author name = Javorik A
| author affiliation = Energy Northwest
| addressee name = 
| addressee affiliation = NRC/Document Control Desk, NRC/NRR
| docket = 05000397
| license number = 
| contact person = 
| case reference number = GO2-17-124
| document type = Letter type:GO, Technical Specifications
| page count = 30
| project = 
| stage = Request
}}

=Text=
{{#Wiki_filter: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 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 APPL ICATION 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 Adop t 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. Attachment 2 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 subm ission 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 , 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 Attachment 1 TECHNICAL SPECIFICATIO NS CHANGES (MARK-UPS)
Definitions 1.1 Columbia Generating Station 1.1-3 Amendment No. 149,169 225  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).
ISOLATI ON 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. IdentifiedLEAKAGE1.LEAKAGE into the drywell such as that from pumpseals or valve packing, that is captured andconducted to a sump or collecting tank; or2.LEAKAGE into the drywell atmosphere from sources that are both specifica lly located and known either not to interfere with the operation ofleakage detection system s or not to be pressure boundary LEAKAGE;
: b. Unidentified LEAKAGEAll LEAKAGE into the drywell that is not identifiedLEAKAGE;c. TotalLEAKAGE Sum of the identified and unidentified LEAKAGE; andd.Pressure Boundary LEAKAGELEAKAGE through a nonisolable fault in a Reactor Coolant System (RCS) component body, pipe wall, or vessel wall.
SLC System 3.1.7 Columbia Generating Station 3.1.7-3 Amendment No. 199,221 225 238 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR  3.1.7.6 Verify each pump develops a flow rate  41.2 gpm at a discharge pressure  1220 psig. In accordance with the Inservice Testing Program INSERVICE TESTING PROGRAM SR  3.1.7.7 Verify flow through one SLC subsystem from pu mp into reactor pressure vessel. In accordance 

with the Surveillance Frequency 

Control Program SR  3.1.7.8 Verify all heat traced piping between storage tank and pump suction valve is unblocked. In accordance 

with the Surveillance Frequency Control Program AND Once within 24 hours aft er 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 atom percent B-10.
Prior to addition to SLC Tank SRVs -  25% RTP 3.4.3 Columbia Generating Station 3.4.3-1 Amendment No. 149,169 225 238, 240 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 SRVs inoperable.
A.1 Reduce THERMAL POWER to < 25% RTP.
4 hours SURV EILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR  3.4.3.1 Verify the safety function lift setpoints of the required SRVs are as follows:
Numberof Setpoint  SRVs    (psig) 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 -60.2Following testing, lift settings shall be within +3%.
In accordan ce with the Inservice Testing Program INSERVICE TESTING PROGRAM SRVs - < 25% RTP 3.4.4 Columbia Generating Station 3.4.4-2 Amendment No. 149,169,225,236,238,240 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR  3.4.4.1 Verify the safety function lift setpoints of the required SRVs are as follows: Numberof Setpoint  SRVs    (psig) 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 -60.2Following testing, lift settings shall be within +3%.
In accordan ce with the Inservice Testing Program INSERVICE TESTING PROGRAM SR  3.4.4.2 -------------------------------NOTE------------------------------
Not required to be performed until 12 hours after reactor steam pressure and flow are adequate to perform the test. 
----------------------------------------------------------------
-----Verify each required SRV opens when manually actuated. In accordance 

with the Surveillance Frequency 

Control Program RCS PIV Leakage 3.4.6 Columbia Generating Station 3.4.6-2 Amendment No. 149,169 225  ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and associat ed Completion Time not met. B.1 Be in MODE 3.
AND B.2 Be in MODE
: 4. 12 hours 36 hours 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  0.5 gpm per nominal inch of valve size up to a maximum of 5 gpm, at an RCS pressure of 1035 psig. The actual test pressure shall be  935 psig. In accordance with Inservice Testing Program the INSERVICE TESTING PROGRAM ECCS - Operating 3.5.1 Columbia Generating Station 3.5.1-4 Amendment No. 169,205,225,229,236 238 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR  3.5.1.1 Verify, for each ECCS injection/spray subsystem, the piping is filled with water from the pump discharge valve to the injection valve. In accordance 

with the 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 manual, power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position. In accordance with the Surveillance 

Frequency 

Control Program SR  3.5.1.3 Verify ADS accumulator backup compressed gas system average pressure in the required bottles is  2200 psig. In accordance with the Surveillance 

Frequency 

Control Program SR  3.5.1.4 Verify each ECCS pump develops the specified flow rate with the specified differential pressure between reactor and suction source.
DIFFERENTIAL PRESSURE BETWEEN REACTOR AND SYSTEM    FLOW RATE            SUCTION SOURCE LPCS  6200 gpm  128 psid LPCI  7200 gpm    26 psid HPCS  6350 gpm  200 psid In accordan ce with the Inservice Testing Program INSERVICE TESTING PROGRAM ECCS - Shutdown 3.5.2 Columbia Generating Station 3.5.2-3 Amendment No. 169,205 225 229 238 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR  3.5.2.3 Verify, for each required ECCS injection/spray subsystem, the piping is filled with water from the pump discharge valve to the injection valve. In accordance 

with the 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 subsystem manual, power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position. In accordance with the Surveillance 

Frequency 

Control Program SR  3.5.2.5 Verify each required ECCS pump de velops the specified flow rate with the specified differential pressure between reactor and suction source.
DIFFERENTIAL PRESSURE BETWEEN REACTOR AND SYSTEM    FLOW RATE            SUCTION SOURCE LPCS  6200 gpm  128 psid LPCI  7200 gpm    26 psid HPCS  6350 gpm  200 psid In accordan ce with the Inservice Testing Program INSERVICE TESTING PROGRAM PCIVs 3.6.1.3 Columbia Generating Station 3.6.1.3-7 Amendment No. 199,208 225 238 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR  3.6.1.3.3 ------------------------------NOTES----------------------------- 1.Valves and blind flanges in high radiation areasmay be verified by use of administrative means.
2.Not required to be met for PCIVs that are open under administrative con trols.----------------
------------------------------------------------
-----Verify each primary containment isolation manual valve and blind flange that is located inside primary containment and not locked, sealed, or otherwise secured and is required to be closed during accident conditions is closed.
Prior to entering MODE 2 or 3 from MODE 4 if 

primary 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) shear isolation valve explosive charge. In accordance with the Surveillance 

Frequency 

Control Program SR  3.6.1.3.5 Verify the isolation time of each power operated, automatic PCIV, except for MSIVs, is within limits. In accordance 

with the Inservice Testing Program INSERVICE TESTING PROGRAM SR  3.6.1.3.6 Verify the isolation time of each MSIV is  3 seconds and  5 seconds. In accordance with the Inservice Testing Program INSERVICE TESTING PROGRAM PCIVs 3.6.1.3 Columbia Generating Station 3.6.1.3-8 Amendment No. 199,208 225 238  SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR  3.6.1.3.7 Verify each automatic PCIV actuates to the isolation position on an actual or simulated isolation signal. In accordance with the Surveillance Frequency Control Program SR  3.6.1.3.8 Verify a representative sample of reactor instrument line EFCVs actuate to the isolation position on an actual or simulated instrument line break signal. In accordance 

with the Surveillance Frequency Control Program SR  3.6.1.3.9 Remo ve and test the explosive squib from each shear isolation valve of the TIP System. In accordance 

with the Surveillance 

Frequency Control Program SR  3.6.1.3.10 Verify the combined leakage rate for all second ary containment bypass leakage paths is  0.04% primary containment volume/day when pressurized to  P a. In accordance with the Primary Containment 

Leakage Rate Testing Program SR  3.6.1.3.11 Verify leakage rate through each MSIV is  16.0 scfh when tested at  25.0 psig. In accordance with the Primary Containment 

Leakage Rate Testing Program SR  3.6.1.3.12 Verify combined leakage rate through hydrostatically tested lines that penetrate the primary containment is within limits. In accordance 

with the Primary Containment 

Leakage Rate Testing Program Reactor Building-to-Suppression Chamber Vacuum Breakers 3.6.1.6 Columbia Generating Station 3.6.1.6-2 Amendment No. 149,169,225,236 238  ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME E. Two or more lines with one or more reactor building-to-suppression chamber va cuum breakers inoperable for opening. E.1 Restore all vacuum breakers in two lines to OPERABLE status.
1 hour F. Required Action and associat ed Completion Time of Condition A, B or E not met. F.1 Be in MODE 3.
AND F.2 Be in MODE 4.
12 hours 36 hours 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 intende d 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 RHR Suppression Pool Cooling 3.6.2.3 Columbia Generating Station 3.6.2.3-2 Amendment No. 169 225 230 238 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR  3.6.2.3.1 Verify each RHR suppre ssion pool cooling subsystem manual, power operated, and automatic 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. In accordance with the Surveillance 

Frequency Control Program SR  3.6.2.3.2 Verify each RHR pump develops a flow rate  7100 gpm through the associated heat exchanger while operating in the suppression pool cooling mode. In accordance 

with the Inservice Testing Program INSERVICE TESTING PROGRAM SCIVs 3.6.4.2   Columbia Generating Station 3.6.4.2-3 Amendment No. 208 225 238 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 valve and blind flange that is not locked, sealed, or otherwise secured, and is required to be closed during accident conditions is closed. 

In accordance with the Surveillance 

Frequency Control Program  

SR  3.6.4.2.2 Verify the isolation time of each power operated, automatic SCIV is within limits. 

In accordance with the Inservice Testing Program INSERVICE TESTING PROGRAM SR  3.6.4.2.3 Verify each automatic SCIV actuates to the isolation position on an actual or simulated automatic isolation signal.
In accordance with the Surveillance 

Frequency Control Program  

Programs and Manuals 5.5 Columbia Generating Station 5.5-4 Amendment 182,205 225 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 andMaintenance of Nuclear Power Plants (ASME OM Code) and applicable Addenda as follows: ASME OM Code and applicable Addenda terminology for inservice testing activities Required Frequencies for performing inservice testing 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 requiredFrequencies 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; andd.Nothing in the ASME OM Code shall be construed to supersede the requirements of any TS.

GO2-17-124 Attachment 2 

TECHNICAL SPECIFICATIONS CLEAN PAGES 

Definitions 1.1    Columbia Generating Station 1.1-3 Amendment No. 149,169 225  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.
SLC System 3.1.7 Columbia Generating Station 3.1.7-3 Amendment No. 199,221 225 238 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR  3.1.7.6 Verify each pump develops a flow rate  41.2 gpm at a discharge pressure  1220 psig. In accordance with the  INSERVICE TESTING PROGRAM SR  3.1.7.7 Verify flow through one SLC subsystem from pu mp into reactor pressure vessel. In accordance 

with the Surveillance Frequency Control Program SR  3.1.7.8 Verify all heat traced piping between storage tank and pump suction valve is unblocked. In accordance 

with the Surveillance 

Frequency Control Program AND Once within 24 hours 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 atom percent B-10.
Prior to addition to 

SLC Tank SRVs -  25% RTP 3.4.3 Columbia Generating Station 3.4.3-1 Amendment No. 149,169 225 238, 240 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 SRVs inoperable.
A.1 Reduce THERMAL POWER to < 25% RTP.
4 hours SURV EILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR  3.4.3.1 Verify the safety function lift setpoints of the required SRVs are as follows:
Numberof Setpoint  SRVs    (psig) 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 -60.2Following testing, lift settings shall be within +3%.
In accordan ce with the  INSERVICE TESTING PROGRAM SRVs - < 25% RTP 3.4.4 Columbia Generating Station 3.4.4-2 Amendment No. 149,169,225,236,238,240 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR  3.4.4.1 Verify the safety function lift setpoints of the required SRVs are as follows: Numberof Setpoint  SRVs    (psig) 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 -60.2Following testing, lift settings shall be within +3%.
In accordan ce with the  INSERVICE TESTING PROGRAM SR  3.4.4.2 -------------------------------NOTE------------------------------
Not required to be performed until 12 hours after reactor steam pressure and flow are adequate to perform the test. 
----------------------------------------------------------------
-----Verify each required SRV opens when manually actuated. In accordance 

with the Surveillance Frequency 

Control Program RCS PIV Leakage 3.4.6 Columbia Generating Station 3.4.6-2 Amendment No. 149,169 225  ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and associat ed Completion Time not met. B.1 Be in MODE 3.
AND B.2 Be in MODE
: 4. 12 hours 36 hours 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  0.5 gpm per nominal inch of valve size up to a maximum of 5 gpm, at an RCS pressure of 1035 psig. The actual test pressure shall be  935 psig. In accordance with the INSERVICE TESTING PROGRAM ECCS - Operating 3.5.1 Columbia Generating Station 3.5.1-4 Amendment No. 169,205,225,229,236 238 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR  3.5.1.1 Verify, for each ECCS injection/spray subsystem, the piping is filled with water from the pump discharge valve to the injection valve. In accordance 

with the 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 manual, power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position. In accordance with the Surveillance 

Frequency 

Control Program SR  3.5.1.3 Verify ADS accumulator backup compressed gas system average pressure in the required bottles is  2200 psig. In accordance with the Surveillance 

Frequency 

Control Program SR  3.5.1.4 Verify each ECCS pump develops the specified flow rate with the specified differential pressure between reactor and suction source.
DIFFERENTIAL PRESSURE BETWEEN REACTOR AND SYSTEM    FLOW RATE            SUCTION SOURCE LPCS  6200 gpm  128 psid LPCI  7200 gpm    26 psid HPCS  6350 gpm  200 psid In accordan ce with the  INSERVICE TESTING PROGRAM ECCS - Shutdown 3.5.2 Columbia Generating Station 3.5.2-3 Amendment No. 169,205 225 229 238 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR  3.5.2.3 Verify, for each required ECCS injection/spray subsystem, the piping is filled with water from the pump discharge valve to the injection valve. In accordance 

with the 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 subsystem manual, power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position. In accordance with the Surveillance 

Frequency 

Control Program SR  3.5.2.5 Verify each required ECCS pump de velops the specified flow rate with the specified differential pressure between reactor and suction source.
DIFFERENTIAL PRESSURE BETWEEN REACTOR AND SYSTEM    FLOW RATE            SUCTION SOURCE LPCS  6200 gpm  128 psid LPCI  7200 gpm    26 psid HPCS  6350 gpm  200 psid In accordan ce with the  INSERVICE TESTING PROGRAM PCIVs 3.6.1.3 Columbia Generating Station 3.6.1.3-7 Amendment No. 199,208 225 238 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR  3.6.1.3.3 ------------------------------NOTES----------------------------- 1.Valves and blind flanges in high radiation areasmay be verified by use of administrative means.
2.Not required to be met for PCIVs that are open under administrative con trols.----------------
------------------------------------------------
-----Verify each primary containment isolation manual valve and blind flange that is located inside primary containment and not locked, sealed, or otherwise secured and is required to be closed during accident conditions is closed.
Prior to entering MODE 2 or 3 from MODE 4 if 

primary 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) shear isolation valve explosive charge. In accordance with the Surveillance 

Frequency 

Control Program SR  3.6.1.3.5 Verify the isolation time of each power operated, automatic PCIV, except for MSIVs, is within limits. In accordance 

with the  INSERVICE TESTING PROGRAM SR  3.6.1.3.6 Verify the isolation time of each MSIV is  3 seconds and  5 seconds. In accordance 

with the INSERVICE TESTING PROGRAM PCIVs 3.6.1.3 Columbia Generating Station 3.6.1.3-8 Amendment No. 199,208 225 238  SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR  3.6.1.3.7 Verify each automatic PCIV actuates to the isolation position on an actual or simulated isolation signal. In accordance with the Surveillance Frequency Control Program SR  3.6.1.3.8 Verify a representative sample of reactor instrument line EFCVs actuate to the isolation position on an actual or simulated instrument line break signal. In accordance 

with the Surveillance Frequency Control Program SR  3.6.1.3.9 Remo ve and test the explosive squib from each shear isolation valve of the TIP System. In accordance 

with the Surveillance 

Frequency Control Program SR  3.6.1.3.10 Verify the combined leakage rate for all second ary containment bypass leakage paths is  0.04% primary containment volume/day when pressurized to  P a. In accordance with the Primary Containment 

Leakage Rate Testing Program SR  3.6.1.3.11 Verify leakage rate through each MSIV is  16.0 scfh when tested at  25.0 psig. In accordance with the Primary Containment 

Leakage Rate Testing Program SR  3.6.1.3.12 Verify combined leakage rate through hydrostatically tested lines that penetrate the primary containment is within limits. In accordance 

with the Primary Containment 

Leakage Rate Testing Program Reactor Building-to-Suppression Chamber Vacuum Breakers 3.6.1.6 Columbia Generating Station 3.6.1.6-2 Amendment No. 149,169,225,236 238  ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME E. Two or more lines with one or more reactor building-to-suppression chamber va cuum breakers inoperable for opening. E.1 Restore all vacuum breakers in two lines to OPERABLE status.
1 hour F. Required Action and associat ed Completion Time of Condition A, B or E not met. F.1 Be in MODE 3.
AND F.2 Be in MODE 4.
12 hours 36 hours 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 intende d 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 RHR Suppression Pool Cooling 3.6.2.3 Columbia Generating Station 3.6.2.3-2 Amendment No. 169 225 230 238 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR  3.6.2.3.1 Verify each RHR suppre ssion pool cooling subsystem manual, power operated, and automatic 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. In accordance with the Surveillance 

Frequency Control Program SR  3.6.2.3.2 Verify each RHR pump develops a flow rate  7100 gpm through the associated heat exchanger while operating in the suppression pool cooling mode. In accordance 

with the  INSERVICE TESTING PROGRAM SCIVs 3.6.4.2 Columbia Generating Station 3.6.4.2-3 Amendment No. 208 225 238 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR  3.6.4.2.1 ------------------------------NOTES----------------------------- 1.Valves and blind flanges in high radiation areasmay be verified by use of administrative controls.2.Not required to be met for SCIVs that are open under administrative con trols.----------------------------------------------------------------
-----Verify each secondary containment isolation manual valve and blind flange that is not locked, sealed, or otherwise secured, and is required to be closed during accident conditions is closed. In accordance with the Surveillance 

Frequency 

Control Program SR  3.6.4.2.2 Verify the isolation time of each power operated, automatic SCIV is within limits. In accordance with the  INSERVICE TESTING PROGRAM SR  3.6.4.2.3 Verify each automatic SCIV actuates to the isolation position on an actual or simulated automatic isolation signal. In accordance with the Surveillance 

Frequency 

Control Program Programs and Manuals 5.5 Columbia Generating Station 5.5-4 Amendment 182,205 225 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}}