ML13316B344

Amend 125 to License DPR-13,approving Changes to Auxiliary Feedwater Sys to Eliminate Single Failure Vulnerability & Provide for Automatic Starting of Third Auxiliary Feedwater Pump

ML13316B344
Person / Time
Site:	San Onofre
Issue date:	04/25/1989
From:	Knighton G Office of Nuclear Reactor Regulation
To:
Shared Package
ML13316B343	List: ML13316B342 ML13316B344 ML13316B345 ML13316B346
References
DPR-13-A-125 NUDOCS 8905040351
Download: ML13316B344 (22)

Text

SaREG&y a V tUNITED STATES o0 NCLEAR REGULATORY COMMISSIOV WASHINGTON, D. C. 20555 SOUTHERN CALIFORNIA EDISON COMPANY SAN DIEGO GAS AND ELECTRIC COMPANY DOCKET NO. 50-206 SAN ONOFRE NUCLEAR GENERATING STATION, UNIT NO. 1 AMENDMENT TO PROVISIONAL OPERATING LICENSE Amendment No. 125 License No. DPR-13

1. The Nuclear Regulatory Commission (the Commission) has found that:

A. The application for dmendment by Southern California Edison Company and San Diego Gas ard Electric Company (the licensee) dated December 8, 1988, as supplemented February 17 and April 5, 1989, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's regulations set forth in 10 CFR Chapter I; B. The facility will operate in conformity with the application, the provisions of the Act, and the regulations of the Commission; C. There is reasonable assuratice (i) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commission's regulations; D. The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E. The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied.

PD

-2

2. Accordingly, the license is amended by changes to the Technical Speci fications as indicated in the attachment to this license amendment, and paragraph 3.B. of Provisional Operating License No. DPR-13 is hereby amended to read as follows:

B. Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No.125, are hereby incorporated in the license. Southern California Edison Company shall operate the facility in accordance with the Technical Specifications, except where otherwise stated in specific license conditions.

3. This license amendment is effective as of the date of its issuance and must be fully implemented no later than 30 days from the date of issuance.

FOR THE NUCLEAR REGUL TORY COMMISSION

'George W Knighton, irector Project irectorat V Division of Reactor Projects -

III, IV, V and Special Projects

Attachment:

Changes to the Technical Specifications Date of Issuance:

April 25, 1989

ATTACHMENT TO LICENSE AMENDMENT NO.125 PROVISIONAL OPERATING LICENSE NO. DPR-13 DOCKET NO. 50-206 Revise Appendix A Technical Specifications by removing the pages identified below and inserting the enclosed pages. The revised pages are identified by the captioned amendment number and contain marginal lines indicating the area of change.

REMOVE INSERT 26 26 26 a 27a 27a 27b 27b 30 30 33n 33n 33 n-1 33o 33o 33p 33p 33q 33q 33 q-1 33r 33r 43d 43d 43 d-1 43 d-1 44g 44g 44j 44j 44k 44k 441 441 44m 44m

-10b

3. With less than the above required loops/trains operable immediately initiate corrective action to return the required loops/trains to operable status as soon as possible; if the remaining operable loop/train is an RHR train, be in Cold Shutdown within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

4. With no loop or train in operation, suspend all operations involving a reduction in boron concentration of the reactor coolant system and immediately initiate corrective action to return one required loop or train to operation.

G. During Mode 5 with reactor coolant loops filled, the following specifications shall apply:

1. At least one residual heat removal (RHR) train shall be operable and in operation*, and either

a. One additional RHR train shall be operable,"* or

b. The secondary side water level of at least two steam generators shall be greater than or equal to 256 inches (wide range).

2. With less than the above required loops/trains operable, or with less than the required steam generator level, immediately initiate corrective action to return the required loops/trains to operable status or to restore the required level as soon as possible.

3. With no RHR train in operation, suspend all operations involving a reduction in boron concentration of the reactor coolant system and immediately initiate corrective action to return the required RHR train to operation.

H. During Mode 5 with reactor coolant loops not filled, the following specifications shall apply:

The RHR pump may be de-energized for up to one hour provided (a) no operations are permitted that would cause dilution of the reactor coolant system boron concentration, and (b) core outlet temperature is maintained at least 40*F below saturation temperature.

• One RHR train may be inoperable for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> for surveillance testing, provided the other RHR train is operable and in operation.

AMENDMENT NO:

71, 125

-26 3.4 TURBINE CYCLE 3.4.1 OPERATING STATUS APLIILTY:

Applies to the operating status of turbine cycle in MODES 1, 2, and 3.

To define conditions of the turbine cycle necessary to ensure the capability to remove decay heat from the core.

SPEC~IIATION:

A minimum turbine cycle steam-relieving capability of 5.706,000 lb/hr (except for testing of the main steam safety valves).

ACTION:

With the turbine cycle steam-relieving capability less than 5,706,000 lb/hr, be in at least HOT STANDBY within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.

A reactor shutdown from power requires subsequent removal of core decay heat. In the event of a reactor trip from high power levels, immediate decay heat removal requirements are satisfied by the steam bypass to the condensers, supplemented by release to the atmosphere. Thereafter, core decay heat can be continuously dissipated via the steam bypass to the condenser or steam dump to atmosphere as feed water in the steam generator is converted to steam by heat absorption. In the event of a planned shutdown, steam release to atmosphere is not required.

The power operated relief valves and the main steam safety valves have a total combined relief capability of 7,629,432 lb/hr. A capability of 5,706,000 lb/hr is required to maintain the pressure in turbine cycle components within ASME code allowable values in the event of full load rejection.

Therefore the limiting conditions for operation can be met with less than the full number of valves in service.

I AMENDMENT NO: ff, $Z, 125

(g)

-27a 3.4.3 AUXILIARY FEEDWATER SYSTEM APPLICABILITY:

Applies to the auxiliary feedwater pumps and valves for MODES 1, 2 and 3.

OBJECTIVE:

To ensure the availability of auxiliary feedwater to remove decay heat from the core.

SPECIFICATION:.

Two trains of auxiliary feedwater, including associated pumps and valves, shall be OPERABLE.

ACION:

A. With one Train of auxiliary feedwater inoperable, restore the inoperable train to OPERABLE status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in HOT SHUTDOWN within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

B. With both Trains of auxiliary feedwater inoperable, be in at least HOT STANDBY within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in HOT SHUTDOWN within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

BASIl:

The OPERABILITY of the auxiliary feedwater system ensures that the Reactor Coolant System can be cooled down-to less than 350'F from normal operating conditions in the event of a total loss of offsite power.

Two auxiliary feedwater trains and the steam system relief valves provide core decay heat removal capability in the event of a sustained loss of off-site power. Either auxiliary feedwater train has the capability to satisfy decay heat removal requirements from the core, with a delivered flow of at least 185 gpm per train with three intact main feedwater lines and pressurized steam generators, 125 gpm per train with two intact main feedwater lines and pressurized steam generators, and 250 gpm per train with two intact main feedwater lines and depressurized steam generators.(1)

AFN System Train A pumps and valves consist of AFW pumps G-10S and G-10 and associated valves, including flow control valves FCV-2300A, FCV-2300B, and FCV-2300C.

AFW System Train B pump and valves consist of AFW pump G-10W and associated valves, including flow control valves FCV-3300A, FCV-3300B, and FCV-3300C.

References:

(1) SCE letter dated November 20, 1987. from M. 0. Medford to NRC Document Control Desk.

AMENDMENT NO: Of 125

-27b 3.4.4 AUXILIARY FEEDHATER STORAGE TANK APPICABiIITY:

Applies to the auxiliary feedwater storage tank for MODES 1, 2 and 3.

To ensure the availability of auxiliary feedwater to remove decay heat.

PECFIAION:

A. The auxiliary feedwater storage tank (AFST) shall be OPERABLE with a usable water volume of at least 190,000 gallons of water.

B. With the AFST inoperable, within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> restore the AFST to OPERABLE status or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in HOT SHUTDOWN within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

BAIS:

The OPERABILITY of the auxiliary feedwater storage tank with the minimum water volume ensures that sufficient water is available to maintain the RCS at HOT STANDBY conditions (including cooldown) for 32 hours3.703704e-4 days <br />0.00889 hours <br />5.291005e-5 weeks <br />1.2176e-5 months <br /> with steam discharge to the atmosphere concurrent with total loss of offsite power. In addition, the water volume will provide sufficient margin to account for spillage that occurs during a main feedwater line break with loss of AFH flow indication prior to isolation of the broken line. Spillage is assumed to last no longer than one hour until the broken loop is identified via RCS Loop Delta-T positive indication that will be evident for the two intact steam generators. The usable water volume limit is specified relative to the bottom of the tank indicated level range (i.e., level tap). The contained water volume below this datum provides a significant margin to the NPSH and vortexing limits above the highest AFW pump suction inlet in the tank, but is not considered available for purposes of this specification.

AMENDMENT NO:

125

-30 TABLE 3.5.1-1 (Continued)

TABLE NOTATION With the reactor trip system breakers in the closed position, the control rod drive system capable of rod withdrawal.

A "TRIP" will stop all rod withdrawal.

The provisions of Specification 3.0.4 are not applicable.

Below the Source Range High Voltage Cutoff Setpoint.

Below the P-7 (At Power Reactor Trip Defeat) Setpoint.

Above the P-7 (At Power Reactor Trip Defeat) Setpoint.

1. 1. 1. 1. 1. Above the P-8 Setpoint ACTION STATEMENTS ACTION I -

With the number of OPERABLE channels one less than the Minimum Channels OPERABLE requirement, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> or be in HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

ACTION 2 -

With the number of OPERABLE channels one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may proceed provided the following conditions are met:

a. The inoperable channel is placed in the tripped condition within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />.

b. The Minimum Channels OPERABLE requirement is met; however, the inoperable channel may be bypassed for up to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> for surveillance testing of other channels per Specification 4.1.

ACTION 3 -

With the number of channels OPERABLE one less than the Minimum Channels OPERABLE requirement and with the THERMAL POWER level:

a. Below the Source Range High Voltage Cutoff Setpoint, restore the inoperable channel to OPERABLE status prior to increasing THERMAL POWER above the Source Range High Voltage Cutoff Setpoint.

b. Above the Source Range High Voltage Cutoff Setpoint but below 10 percent of RATED THERMAL POWER, restore the inoperable channel to OPERABLE status prior to increasing THERMAL POWER above 10 percent of RATED THERMAL POWER.

ACTION 4 -

With the number of OPERABLE channels one less than the Minimum Channels OPERABLE requirement suspend all operations involving positive reactivity changes.

ACTION 5 - With the number of OPERABLE channels one less than the Minimum Channels OPERABLE requirement, verify compliance with the SHUTDOWN MARGIN requirements of Specification 3.5.2 as applicable, within I hour and at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> thereafter.

AMENDMENT NO: 50,5,$3,111, 111,125

-33n 3.5.6 ACCIDENT MONITORING INSTRUMENTATION APPLICABILITY:

MODES 1, 2 and 3.

OBJECTIVE:

To ensure reliability of the accident monitoring instrumentation.

SPECIFICATION:

The accident monitoring instrumentation channels shown in Table 3.5.6-1 shall be OPERABLE.

ACTION:

A. With the number of OPERABLE accident monitoring instrumentation channels less than the Total Number of Channels shown in Table 3.5.6-1, except as noted in ACTIONS B and C, either restore the inoperable channel(s) to OPERABLE status within 7 days, or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

B. With one or more channels of Auxiliary Feedwater Flow Rate or Steam Generator Water Level or RCS Loop Delta-T indication inoperable, restore the inoperable channel(s) to OPERABLE status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or be in at least HOT STANDBY within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in at least HOT SHUTDOWN within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

C. With channels from more than one type of Auxiliary Feedwater Flow Indication inoperable, restore the inoperable channel(s) to OPERABLE status such that no more than one type of indication has an inoperable channel(s) within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> or be in at least HOT STANDBY within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in at least HOT SHUTDOWN within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

D. With the number of OPERABLE accident monitoring instrumentation channels less than the MINIMUM CHANNELS OPERABLE requirements of Table 3.5.6-1, except as noted in ACTIONS B and C, either restore the inoperable I

channel(s) to OPERABLE status within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

E. The provisions of Specification 3.0.4 are not applicable for Specifications A and D above.

BASIS:

The OPERABILITY of the accident monitoring instrumentation ensures that sufficient information is available on selected plant parameters to monitor and assess these variables during and following an accident. This capability is consistent with the recommendations of Regulatory Guide 1.97, "Instrumentation for Light-Water-Cooled Nuclear Power Plants to Assess Plant Conditions During and Following an Accident,"

December 1975 and NUREG-0578, "TMI-2 Lessons Learned Task Force Status Report and Short-Term Recommendations."

The Auxiliary Feedwater flow indication is subject to the more restrictive ACTION requirements for the AFW system. In order to satisfy decay heat removal requirements and minimize AMENDMENT NO:

-33n-1 the potential for exceeding water hammer flow limits for a main feedwater line break upstream of the in-containment check valve, the OPERABILITY of AFH Train B is subject to the ability to equalize flow to the steam generators.

Verification of equalization is provided by the AFW flow transmitters. If the capability to equalize flow or the ability to verify equalization is not available, Train A would be utilized to provide the necessary decay heat removal capability. AFW Train A provides adequate flow for this scenario without reliance on operator action to equalize flow.(3) The steam generator wide range level indicators and the RCS loop delta-T indicators provide backup means for verification of auxiliary feedwater flow to the steam generators, and also provide alternate means for identification of a broken loop.

References:

(1)

NRC letter dated July 2, 1980, from D. G. Eisenhut to all pressurized water reactor licensees.

(2)

NRC letter dated November 1, 1983, from D. G. Eisenhut to all Pressurized Water Reactor Licensees, NUREG-0737 Technical Specification (Generic Letter No. 83-37).

(3)

SCE letter dated November 6, 1987, from M. 0. Medford to NRC Document Control Desk.

AMENDMENT NO:

125

TABLE 3.5.6-1 ACCIDENT MONITORING INSTRUMENTATION MINIMUM TOTAL NO.

CHANNELS INSTRUMENT OF CHANNELS OPERABLE Pressurizer Hater Level 3

2 Auxiliary Feedwater Flow Indication*

o Auxiliary Feedwater Flow Rate 1/steam generator 1/steam generator o Steam Generator Hater Level (Hide Range) 1/steam generator 1/steam generator o Reactor Coolant System Loop Delta-T Indication i/loop 1/loop Reactor Coolant System Subcooling Margin Monitor 2

1 PORV Position Indicator (Limit Switch) 1/valve 1/valve PORV Block Valve Position Indicator (Limit Switch) 1/valve 1/valve Safety Valve Position Indicator (Limit Switch) 1/valve 1/valve Containment Pressure (Hide Range) 2 1

Refueling Hater Storage Tank Level 2

1 Containment Sump Hater Level (Narrow Range)

• 2 Containment Hater Level (Hide Range) 2 H

Neutron Flux (Hide Range) 2 1

0 Auxiliary feedwater flow indication for each steam generator is provided by one channel of auxiliary feedwater flow rate (Train B), one channel of environmentally qualified steam generator wide range level (Train A), and one channel of RCS Loop Delta-T indication. These comprise the three types of indication of auxiliary feedwater flow for each steam generator.

t-n Operation may continue up to 30 days with one less than the total number of channels OPERABLE.

-3 3 p 3.5.7 AUXILIARY FEEDHATER INSTRUMENTATION APPLICABILITY:

Applies to the auxiliary feedwater system instrumentation and interlocks in MODES 1, 2 and 3.

OBJECTIVE:

To ensure reliability of automatic initiation of the auxiliary feedwater system.

SPECIFICATIONS:

A. The instrumentation channels shown in Table 3.5.7-1 shall be OPERABLE with their trip setpoints set consistent with the Trip Setpoint column of Table 3.5.7-2.

B. With an instrumentation channel trip setpoint less conservative than the value shown in the Allowable Values column of Table 3.5.7-2, declare the channel inoperable and apply the applicable ACTION requirement of Table 3.5.7-1 until the channel is restored to OPERABLE status with the trip setpoint adjusted consistent with the Trip Setpoint Value.

C. With one instrumentation channel inoperable, take the action shown in Table 3.5.7-1.

The OPERABILITY of the auxiliary feedwater instrumentation ensures that 1) the associated action will be initiated when the parameter monitored by each channel or combination thereof reaches its setpoint, 2) the specified coincidence logic is maintained, 3) sufficient redundancy is maintained to permit a channel to be out of service for testing or maintenance, and 4) sufficient system functional capability is available from diverse parameters.

The OPERABILITY of this instrumentation is required to provide the overall reliability, redundancy, and diversity assumed available for the protection and mitigation of accident and transient conditions. The operation of this instrumentation is consistent with the assumptions used in the accident analyses.

References:

(1)

NRC letter dated July 2, 1980, from D. G. Eisenhut to all pressurized water reactor licensees.

AMENDMENT NO: $$,125

AUXILIARY FEEDHATER INSTRUMENTATION MINIMUM TOTAL NO.

CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTI10

a. Manual Actuation 2

1 2

1. 2, 3 12

b. Automatic Actuation Logic 2

1 2

1, 2, 3 13

c.

Steam Generator Water Level-Low

i. Train A 3

2 2

1. 2, 3 14, 15 0

ii. Train 8 3

2 2

1, 2, 3 14, 15

d. AFH Train Interlocks'

i. Low Flow Train B/

Start Train A Flow

1) Start Pump GlOS/Open Pump GlO 2

1 2

1, 2. 3 35, 36 Discharge Valve CV-2620, AND

2) Start Pump GlO/Open Pump GlOS 2

1 2

1, 2, 3 35, 36 Discharge Valve MOV-1202.

ii. Normal Flow Train 8/

Stop Train A Flow

1) Stop Pump GlOS/Close Pump GlO 2

2" 2

1, 2, 3 35, 36 Discharge Valve CV-2620, OR

2) Stop Pump GlO/Close Pump GlOS 2

2" 2

1, 2, 3 35, 36 Discharge Valve MOV-1202.

Ln A total of 4 flow switches monitor Train B flow and each switch represents a channel which provides the specified signals to Train A.

Only I of 2 Channels is required to trip if 1 Channel has been disconnected per the requirements of ACTION 35.

- 33q-1 ACTION 12 - With the number of OPERABLE channels one less than the Total Number of Channels, restore the inoperable channel to OPERABLE status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or be in at least HOT STANDBY within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in at least HOT SHUTDOWN within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

ACTION 13 - With the number of OPERABLE channels one less than the Minimum Channels OPERABLE requirement, restore the inoperable channel to OPERABLE status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or be in at least HOT STANDBY within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in at least HOT SHUTDOWN within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />; however, one channel may be bypassed for up to 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> for surveillance testing per Specification 4.1.8 provided the other channel is OPERABLE.

ACTION 14 - With the number of OPERABLE channels one less than the Total Number of Channels, operation may proceed until performance of the next required CHANNEL TEST provided the inoperable channel is placed in the tripped condition within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />, or an operator shall assume continuous surveillance and actuate manual initiation of auxiliary feedwater, if necessary.

ACTION 15 - With more than one channel inoperable, an operator shall assume continuous surveillance and actuate manual initiation of auxiliary feedwater, if necessary. Restore the system to no more than one channel inoperable within 7 days, or be in HOT STANDBY within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in HOT SHUTDOWN within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

ACTION 35 - With the number of OPERABLE channels one less than the Total Number of Channels, restore the inoperable channel to OPERABLE status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or disconnect the inoperable channel within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.

ACTION 36 - With the total number of OPERABLE channels monitoring Train B flow less than 3, restore the number of OPERABLE channels to no less than 3 within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or be in at least HOT STANDBY within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in at least HOT SHUTDOWN within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

AMENDMENT NO:

125

TABLE 3.5.7-2 AUXILIARY FEEDHATER INSTRUMENTATION SETPOINTS FUNCTIONAL UNIT SETPOINT ALLOWABLE VALUES

a. Manual Actuation Not Applicable Not Applicable

b. Automatic Actuation Logic Not Applicable Not Applicable

c. Steam Generator Hater Level-Low 2 238 inch level of wide 2 233 inch level of range instrument span wide range instrument for each steam generator span for each steam generator

d. AFH Train Interlocks

i. Decreasing Flow in Train B/

Start Train A Flow 23 gpmh

> 10 gpm ii. Increasing Flow in Train B/

Stop Train A Flow 37 gpmA 1 48 gpm

• Each flow switch monitoring Train B flow utilizes its set and reset points for permissive signals for starting and stopping Train A.

-43d TABLE 4.1.2 (continued)

Check Frequency

1. At least two required

1. Once per 7 days reactor coolant pumps are operable with correct breaker align ments and indicated power availability.

2. The steam generators

2. Once per 12 associated with the two hours required reactor coolant pumps are operable with secondary side water level 1 256 inches (wide range).

3. At least one reactor

3. Once per 12 coolant loop is in hours operation and circulating reactor coolant.

c. Per Technical Specification 3.1.2.F, in Mode 4 verify

1. At least two required

1. Once per 7 days (RC or RHR) pumps are operable with correct breaker alignments and indicated power availability.

2. The required steam

2. Once per 12 generators are operable hours with secondary side water level 1 256 inches (wide range).

3. At least one reactor

3. Once per 12 coolant loop/RHR train hours is in operation and circulating reactor coolant.

d. Per Technical Specifications 3.1.2.G and 3.1.2.H. in Mode 5 verify, as applicable:

AMENDMENT NO.:17,12,125

-43d-1 TABLE 4.1.2 (continued)

Check Frequency

1. At least one RHR train

1. Once per 12 is in operation and hours circulating reactor coolant.

2. When required, one

2. Once per 7 additional RHR train is days operable with correct pump breaker alignments and indicated power availability.

3. When required, the

3. Once per 12 secondary side water level hours of at least two steam generators is _ 256 inches (wide range).

e. Per Technical Specification

e. Once per 12 3.8.A.3, in Mode 6, with water hours level in refueling pool greater than elevation 40 feet 3 inches, verify that at least one method of decay heat removal is in operation and circulating reactor coolant at a flow rate of at least 400 gpm.

f. Per Technical Specification 3.8.A.4, in Mode 6, with water level in refueling pool less than elevation 40 feet 3 inches, verify

1. At least one decay heat

1. Once per 12 removal method is in hours operation and circulating reactor coolant.

2. One additional decay heat 2. Once per 7 removal method is operable days with correct pump breaker alignments and indicated power availability.

16. RWST

a. Verify volume _ 50 ft. plant

a. Monthly when the Contained elevation reactor is critical Water Volume and prior to return of criticality when a period of subcriticality extends the surveillance beyond 1 month AMENDMENT NO.: 122,125

-44g TABLE 4.1.5-1 ACCIDENT MONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTS CHANNEL CHANNEL INSTRUMENT CHECK CALIBRATION Pressurizer Water Level M

R Auxiliary Feedwater Flow Indication*

o Auxiliary Feedwater Flow Rate M

R o Steam Generator Water Level (Wide Range)

M R

o Reactor Coolant System Loop Delta-T Indication M

R Reactor Coolant System Subcooling Margin Monitor M

R PORV Position Indicator M

R PORV Block Valve Position Indicator M

R Safety Valve Position Indicator M

R Containment Pressure (Wide Range)

M R

Refueling Water Storage Tank Water Level M

R Containment Sump Water Level (Narrow Range)

M R

Containment Water level (Wide Range) 1 R

Neutron Flux (Wide Range)

M R**

• See footnote of Table 3.5.6-1.

• • Neutron detectors may be excluded from CHANNEL CALIBRATION.

AMENDMENT NO: $$,gff,125

(4)

-44 4.1.8 AUXILIARY FEEDWATER INSTRUMENTATION APPLICABILITY:

Applies to the auxiliary feedwater instrumentation and interlocks in MODES 1, 2 and 3.

OBJECTIVE:

To ensure reliability of automatic initiation of the auxiliary feedwater system.

SPECIFICATION:

A. Each instrumentation channel shall be demonstrated OPERABLE by the performance of the surveillance requirements specified in Table 4.1.8-1.

DAMS:

The surveillance requirements specified for this instrumentation ensure that the overall system functional capability is maintained comparable to the original design standards. The periodic surveillance tests performed at the minimum frequencies are sufficient to demonstrate this capability.

References:

(1)

NRC letter dated July 2, 1980, from D. G. Eisenhut to all pressurized water reactor licensees.

AMENDMENT NO: $$,125

TABLE 4.1.8-1 AUXILIARY FEEDHATER INSTRUMENTATION SURVEILLANCE REQUIREMENTS TRIP ACTUATING DEVICE MODES IN WHICH CHANNEL CHANNEL CHANNEL OPERATIONAL SURVEILLANCE FUNCTIONAL UNIT CHECK CALIBRATION TEST TEST REOUIRED

a. Manual N/A N/A N/A R

1, 2, 3

b. Automatic Actuation Logic N/A N/A N

N/A 1, 2, 3

c. Steam Generator Hater S

R M

N/A 1, 2, 3 Level-Low

d. AFM Train Interlocks N/A R

M N/A 1, 2, 3 O

-441 4.1.9 AUXILIARY FEEDNATER SYSTEM SURVEILLANCE APPLICAB&ILTY:

Applies to the auxiliary feedwater pumps and valves for MODES 1. 2 and 3.

QflECTfMUE:

To ensure the reliability of the auxiliary feedwater system.

SPECIFICATION:

A. Each auxiliary feedwater pump shall be demonstrated OPERABLE by testing each pump in accordance with Section XI of the ASME Boiler and Pressure Vessel Code and applicable Addenda as required by 10 CFR 50.55a(g),

except where specific written relief has been granted by the NRC pursuant to 10 CFR 50.55a(g)(6)(i).

B. At least once per 31 days an inspection shall be made to verify that each non-automatic valve in the emergency flow path that is not locked, sealed, or otherwise secured in position is in its correct position.

C. Each auxiliary feedwater Train shall be demonstrated OPERABLE at least once per 18 months by:

1. Verifying that the AFW Train B pump starts as designed automatically upon receipt of an auxiliary feedwater actuation test signal.

2. Verifying that the AFN Train A motor driven pump starts as designed automatically upon receipt of auxiliary feedwater actuation AND Train B low flow test signals. Subsequently, verify the pump stops upon receipt of a Train B positive flow test signal.

3. Within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> after entering MODE 3, verifying that the AFW Train A steam driven pump enters warm-up mode upon receipt of an auxiliary feedwater actuation test signal.

Subsequently, verify pump starts upon receipt of a Train B low flow test signal, and returns to warm-up mode upon receipt of Train B positive flow test signal.

4. Verifying that each automatic valve in the flow path actuates to its correct position upon receipt of actuation test signals.

D. When the reactor coolant system pressure remains less than 500 psig for a period longer than thirty (30) days, flow tests shall be performed to verify the emergency flow paths from the*auxiliary feedwater storage tank to each steam generator, using each motor driven auxiliary feedwater pump prior to increasing AMENDMENT NO: 6$,99,125

-44m reactor coolant system pressure above 500 psig. The flow tests shall be conducted with the auxiliary feedwater system valves in their emergency alignment.

Hithin 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> after entering MODE 3, the steam driven auxiliary feedwater pump shall be similarly tested.

E. The provisions of Specification 4.0.4 are not applicable for entry into MODE 3 for the steam driven auxiliary feedwater pump. However, the steam driven AFW pump must be OPERABLE in all other respects.

BASIS:

The OPERABILITY of the auxiliary feedwater system ensures that the Reactor Coolant System can be cooled down to less than 350*F from normal operating conditions in the event of a total loss of offsite power.

The design of the Auxiliary Feedwater System further ensures sufficient AFH flow into the intact feedwater lines without exceeding pump run-out or water hammer limits for any applicable design basis event with or without concurrent loss of offsite power and a single active failure.(,3)

References:

(1)

NRC letter dated July 2, 1980 from D. G. Eisenhut to all pressurized water reactor licensees.

(2)

SCE letter dated November 6, 1987 from M. 0. Medford to NRC Document Control Desk.

(3)

SCE letter dated November 20, 1987, from M. 0. Medford to NRC Document Control Desk.

AMENDMENT NO: 0$,125