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{{Adams
#REDIRECT [[TSTF-09-10, TSTF-425, Revision 3, Relocate Surveillance Frequencies to Licensee Control - RITSTF Initiative 5b, Sections 3.7.6 - B 3.3.8]]
| number = ML090850630
| issue date = 03/18/2009
| title = TSTF-425, Revision 3, Relocate Surveillance Frequencies to Licensee Control - RITSTF Initiative 5b, Sections 3.7.6 - B 3.3.8
| author name =
| author affiliation = B & W Owners Group, BWR Owners Group, Combustion Engineering Owners Group, PWR Owners Group, Technical Specifications Task Force, Westinghouse Owners Group
| addressee name =
| addressee affiliation = NRC/NRR
| docket = PROJ0753
| license number =
| contact person =
| case reference number = TSTF-09-10
| document report number = BWROG-88, Rev. 0, TSTF-425, Rev 3
| package number = ML090850642
| document type = Technical Specifications
| page count = 478
| project =
| stage = Other
}}
 
=Text=
{{#Wiki_filter:CST 3.7.6 3.7 PLANT SYSTEMS
 
====3.7.6 Condensate====
Storage Tank (CST)
LC0 3.7.6 The CST shall be OPERABLE.
APPLICABILITY:
MODES 1, 2, and 3, MODE 4 when steam generator is relied upon for heat removal.
ACTIONS CONDITION A. CST inoperable.
B. Required Action and associated Completion Time not met. REQUIRED ACTION A Verify by administrative means OPERABILITY of backup water supply.
A.2 Restore CST to OPERABLE status.
B.l Be in MODE 3. AND B.2 Be in MODE 4, without reliance on steam generator for heat removal.
COMPLETION TIME 4 hours AND Once per 12 hours thereafter 7 days 6 hours [24] hours P SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.6.1 Verify the CST level is 2 [110,000 gal]. u-r-clrrrrr WOG STS 3.7.6-1 Rev. 3.0, 03/31/04 CST 3.7.6 3.7 PLANT SYSTEMS 3.7.6 Condensate Storage Tank (CST)LCO 3.7.6 The CST shall be OPERABLE.APPLICABILITY:
ACTIONS MODES 1, 2, and 3, MODE 4 when steam generator is relied upon for heat removal.CONDITION REQUIRED ACTION COMPLETION TIME A.CST inoperable.
A.1 Verify by administrative 4 hours means OPERABILITY of backup water supply.AND Once per 12 hours thereafter AND A,2 Restore CST to 7 days OPERABLE status.B.Required Action and B.1 Be in MODE 3.6 hours associated Completion Time not met.AND B.2 Be in MODE 4, without[24]hours reliance on steam generator for heat removal.SURVEILLANCE REQUIREMENTS SR 3.7.6.1 WOG STS SURVEILLANCE Verify the CST level is[110,000 gal].3.7.6-1 FREQUENCY Rev.3.0, 03/31/04 CCW System
 
====3.7.7 SURVEILLANCE====
REQUIREMENTS - SURVEILLANCE SR 3.7.7.1 -------------------------------NOTE
.............................. Isolation of CCW flow to individual components does not render the CCW System inoperable. Verify each CCW manual, power operated,'and automatic valve in the flow path servicing safety related equipment, that is not locked, sealed, or otherwise secured in position, is in the correct position.
SR 3.7.7.2 Verify each CCW automatic valve in the flow path that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal. SR 3.7.7.3 Verify each CCW pump starts autornatically on an actual or simulated actuation signal.
WOG STS FREQUENCY Rev. 3.0, 03/31/04 SURVEILLANCE REQUIREMENTS SURVEILLANCE CCW System 3.7.7 FREQUENCY SR 3.7.7.1 SR 3.7.7.2 SR 3.7.7.3 WOG STS-------------------------------NOTE------------------------------
Isolation of CCW flow to individual components does not render the CCW System inoperable.
Verify each CCW manual, power operated,'
and automatic valve in the flow path servicing safety related equipment, that is not locked, sealed, or otherwise secured in position, is in the correct position.Verify each CCW automatic valve in the flow path that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.Verify each CCW pump starts automatically on an actual or simulated actuation signal.3.7.7-2 W8]months Rev.3.0, 03/31/04 SWS 3.7.8 SURVEILLANCE REQUIREMENTS - - SURVEILLANCE SR 3.7.8.1 ...............................
NOTE .............................. Isolation of SWS flow to individual components does not render the SWS inoperable.
Verify each SWS manual, power operated, and automatic valve in the flow path servicing safety related equipment, that is not locked, sealed, or otherwise secured in position, is in the correct position.
SR 3.7.8.2 Verify each SWS automatic valve in the flow path that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal. SR 3.7.8.3 Verify each SWS pump starts automatically on an actual or simulated actuation signal. - - FREQUENCY
-.%rn A,. ...,..- a*" yr,L 1-J *v**U, I. 1 .*CI -cmw / [I81 months f. ". WOG STS Rev. 3.0, 03/31/04 SURVEILLANCE REQUIREMENTS SURVEILLANCE SWS 3.7.8 FREQUENCY SR 3.7.8.1 SR 3.7.8.2 SR 3.7.8.3 WOGSTS-------------------------------NOTE
------------------------------
Iso/ation of SWS flow to individual components does not render the SWS inoperable.
Verify each SWS manual, power operated, and automatic valve in the flow path servicing safety related equipment, that is not locked, sealed, or otherwise secured in position, is in the correct position.Verify each SWS automatic valve in the flow path that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.Verify each SWS pump starts automatically on an actual or simulated actuation signal.3.7.8-2 IT!8)monthsRev.3.0, 03/31/04 UHS 3.7.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE
[ Verify water level of UHS is 1 [562] ft [mean sea level]. [ Verify average water temperature of UHS is 5 [90l0F. SR 3.7.9.3 [ Operate each cooling tower fan for r [I51 minutes. [ Verify each cooling tower fan starts automatically on an actual or simulated actuation signal.
WOG STS FREQUENCY r, r [24] hours ] E4 hours "? 1 Rev. 3.0, 03/31/04 UHS 3.7.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.9.1[Verify water level of UHS is;;:=[562]ft[mean sea level].[24]hour:;-J.6er:fi"[Verify each cooling tower fan starts automatically on an actual or simulated actuation signal.[Verify average water temperature of UHS is::;[90tF.SR 3.7.9.4 SR 3.7.9.2_S_R_3._7_.9_.3
[_O_pe_r_at_e_e_a_C_h_c_oo_l_in_
9_to_w_e_r_f_an_fO_r_2_[_15_]_m_i_n_ut_e_s*----if--...,I'[08]months U__Insert 1 WOGSTS 3.7.9-2 Rev.3.0, 03/31/04 CREFS 3.7.10 ACTIONS (continued)
CONDITION D. Required Action and associated Completion Time of Condition A not met [in MODE 5 or 6, or] during movement of [recently] irradiated fuel assemblies.
E. Two CREFS trains inoperable
[in MODE 5 or 6, or] during movement of [recently]
irradiate fuel assemblies.
F. Two CREFS trains inoperable in MODE 1, 2, 3, or 4 for reasons other than Condition
: 6. REQUIRED ACTION D.1 --------------
NOTE --------------
[ Place in toxic gas protection mode if automatic transfer to toxic gas protection mode is inoperable.
] -+-----------------------------------
Place OPERABLE CREFS train in emergency mode.
D.2 Suspend movement of [recently] irradiated fuel assemblies.
*.I Suspend movement of
[recently] irradiated fuel assemblies.
F.1 Enter LC0 3.0.3. COMPLETION TIME Immediately Immediately Immediately Immediately SURVEILLANCE REQUIREMENTS - -- - - ---- - - I SURVEILLANCE ( FREQUENCY SR 3.7.10.1 Operate each CREFS train for [2 10 continuous hours with the heaters operating or (for systems without heaters) 2 15 minutes].
WOG STS 3.7.10-2 Rev. 3.0, 03/31/04 CREFS 3.7.10 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME D.Required Action and D.1--------------N 0 TE--------------
associated Completion
[Place intoxicgas Time of Condition A not protection mode if met[in MODE 5 or 6, or]automatic transfer to toxic during movement of gas protection mode is[recently}
irradiated fuel inoperable.
]assemblies.
-...-----------------------------------
Place OPERABLE CREFS Immediately train in emergency mode.OR D.2 Suspend movement of Immediately
[recently]
irradiated fuel assemblies.
--_.._-,,-_._---E.Two CREFS trains E.1 Suspend movement of Immediately inoperable
[in MODE 5[recently]
irradiated fuel or 6, or]during assemblies.
movement of[recently}
irradiate fuel assemblies.
F.Two CREFS trains F.1 Enter LCO 3.0.3.Immediately inoperable in MODE 1, 2, 3, or 4 for reasons other than Condition B.SURVEILLANCE REQUIREMENTS SR 3.7.10.1 WOGSTS SURVEILLANCE Operate each CREFS train for[;::: 10 continuous hours with the heaters operating or (for systems without heaters);:::
15 minutes).3.7.10-2 FREQUENCY Rev.3.0, 03/31/04 CREFS 3.7.10 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY - SR 3.7.10.2 Perform required CREFS filter testing in accordance In accordance with the [Ventilation Filter Testing Program (VFTP)]. with [VFTP] SR 3.7.10.3 Verify each CREFS train actuates on an actual or simulated actuation signal. SR 3.7.10.4 the adjacent [turbine building] during the pressurization mode of operation at a makeup flow rate of I [3000] cfm. WOG STS Rev. 3.0, 03/31/04 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE CREFS 3.7.10 FREQUENCY SR 3.7.10.2 SR 3.7.10.3 SR 3.7.10.4 WOGSTS Perform required CREFS filter testing in accordance with the[Ventilation Filter Testing Program (VFTP)J.Verify each CREFS train actuates on an actual or simulated actuation signal.Verify one CREFS train can maintain a positive pressure of[0.125]inches water gauge, relative to the adjacent[turbine building]during the pressurization mode of operation at a makeup flow rate of=s;[3000)cfm.3.7.10-3 In accordance with[VFTPJ[[18]months on a STAGGERED.TEST BASIS@_
-.----Rev.3.0.03/31/04 CREATCS 3.7.1 1 ACTIONS (continued)
I - CONDITION I REQUIRED ACTION I COMPLETION TIME Immediately E. Two CREATCS trains inoperable in MODE 1, 2, 3, or 4. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY E.l Enter LC0 3.0.3. SR 3.7.11.1 remove the assumed heat load. WOG STS Rev. 3.0, 03/31/04 ACTIONS (continued)
CONDITION E.Two CREATCS trains inoperable in MODE 1, 2,3,or4.E.1 REQUIRED ACTION Enter LCO 3.0.3.CREATCS 3.7.11 COMPLETION TIME Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.11.1 WOGSTS Verify each CREATCS train has the capability to remove the assumed heat load.3.7.11-2[pal monthsInSertl Rev.3.0, 03/31/04 ECCS PREACS 3.7.12 SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.7.12.1 Operate each ECCS PREACS train for
[2 A0 continuous hours with the heaters operating or (for systems without heaters) 2 15 minutes].
SR 3.7.12.2 Perform required ECCS PREACS filter testing in accordance with the [Ventilation Filter Testing Program (VFTP)].
SR 3.7.12.3 Verify each ECCS PREACS train actuates on an actual or simulated actuation signal.
SR 3.7.12.4 Verify one ECCS PREACS train can maintain a pressure 5 [-0.1251 inches water gauge relative to atmospheric pressure during the [post accident]
mode of operation at a flow rate of 5 [3000] cfm. SR 3.7.12.5 [ Verify each ECCS PREACS filter bypass damper can be closed. WOG STS FREQUENCY - 31 days k-, In accordance with the [VFTP] - [I81 months 6 e [18] months on a STAGGERED
~f, TEST BASIS C \/67 [18] month;] 1 Rev. 3.0, 03/31/04 SURVEILLANCE REQUIREMENTS SURVEILLANCE ECCS PREACS 3.7.12 FREQUENCY SR 3.7.12.1 SR 3.7.12.2 SR 3.7.12.3 SR 3.7.12.4 SR 3.7.12.5 WOGSTS Operate each ECCS PREACS train for[;:: 10 continuous hours with the heaters operating or (for systems without heaters);:: 15 minutes].Perform required ECCS PREACS filter testing in accordance with the[Ventilation Filter Testing Program (VFTP)].Verify each EGGS PREACS train actuates on an actual or simulated actuation signal.Verify one ECCS PREAGS train can maintain a pressure S[-0.125]inches water gauge relative to atmospheric pressure during the[post accident]mode of operation at a flow rate of:5[3000]cfm.[Verifyeach EGCS PREAGS filter bypass damper can be closed.3.7.12-2(Weill In accordance with the[VFTP][118]months on a STAGGERED TEST BASIS Rev.3.0, 03/31/04 FBACS 3.7.13 ACTIONS (continued)
CONDITION C. [ Required Action and associated Completion Time of Condition A or B not met in MODE 1, 2, 3, or 4. Two FBACS trains inoperable in MODE 1, 2,3, or 4 for reasons other than Condition B. D. Required Action and associated Completion Time [of Condition A] not met during movement of [recently] irradiated fuel assemblies in the fuel building. E. Two FBACS trains inoperable during movement of [recently] irradiated fuel assemblies in the fuel building. REQUIRED ACTION C.l Be in MODE 3. AND C.2 Be in MODE 5. D.l Place OPERABLE FBACS train in operation.
D.2 Suspend movement of [recently] irradiated fuel assemblies in the fuel building.
E.l Suspend movement of [recently] irradiated fuel assemblies in the fuel building.
COMPLETION TIME 6 hours 36 hours ] lmmediately lmmediately lmmediately SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.7.13.1 Operate each FBACS train for
[2 10 continuous hours with the heaters operating or (for systems without heaters) r 15 minutes].
WOG STS 3.7.13-2 FREQUENCY 6 days f7 Rev. 3.0. 03/31/04 FBACS 3.7.13 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME C.[Required Action and C.1 Be in MODE 3.6 hours associated Completion Time of Condition A or B AND not met in MODE 1, 2, 3, or 4.C.2 Be in MODE 5.36 hours]OR Two FBACS trains inoperable in MODE 1, 2, 3, or 4 for reasons other than Condition B.D.Required Action and 0.1 Place OPERABLE FBACS Immediately associated Completion train in operation.
Time[of Condition A]not met during movement of OR[recently]
irradiated fuel assemblies in the fuel D.2 Suspend movement of Immediately building.[recently]
irradiated fuel assemblies in the fuel building.E.Two FBACS trains E.1 Suspend movement of Immediately inoperable during[recently]
irradiated fuel movement of[recently]
assemblies in the fuel irradiated fuel building.assemblies in the fuel building.SURVEILLANCE REQUIREMENTS SR 3.7.13.1 WOGSTS SURVEILLANCE Operate each FBACS train for10 continuous hours with the heaters operating or (for systems without heaters)15 minutes].3.7.13-2 FREQUENCY Rev.3.0, 03/31/04 FBACS 3.7.13 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.7.13.2 Perform required FBACS filter testing in accordance In accordance with the [Ventilation Filter Testing Program (VFTP)]. with the D/FTP] SR 3.7.13.3 [ Verify each FBACS train actuates on an actual or [I 81 month simulated actuation signal.
[ SR 3.7.13.4 Verify one FBACS train can maintain a pressure 5 [-0.1251 inches water gauge with respect to atmospheric pressure during the [post accident]
mode of operation at a flow rate 5 [20,000] cfm. SR 3.7.73.5 WOG STS Rev. 3.0, 03/31/04 SURVEILLANCE REQUIREMENTS (continued)
FBACS 3.7.13 SURVEILLANCE FREQUENCY SR 3.7.13.2 Perform required FBACS filter testing in accordance In accordance with the[Ventilation Filter Testing Program (VFTP)].with the[VFTP]SR 3.7.13.3[Verify each FBACS train actuates on an actual or@8]month:f 1 simulated actuation signal.
)SR 3.7.13.4 Verify one FBACS train can maintain a pressure8]months on a::;[-0.125]inches water gauge with respect to TAGGERED atmospheric pressure during the[postaccident]
TESTBASISmode of operation at a flow rate::;[20,000)cfm..q;:wfj)SR 3.7.13.5[Verify each FBACS filter bypass damper can be W 8]months]l closed.(Inseytl WOGSTS 3.7.13-3 Rev.3.0, 03/31/04 PREACS 3.7.14 3.7 PLANT SYSTEMS 3.7.14 Penetration Room Exhaust Air Cleanup System (PREACS)
LC0 3.7.14 Two PREACS trains shall be OPERABLE.
APPLICABILITY: MODES 1, 2, 3, and 4. ACTIONS CONDITION A. One PREACS train inoperable. B. Two PREACS trains inoperable due to inoperable penetration room boundary.
C. Required Action and associated Completion Time not met. REQUIRED ACTION A.1 Restore PREACS train to OPERABLE status.
B.l Restore penetration room boundary to OPERABLE status. C.1 Be in MODE 3. AND C.2 Be in MODE 5. COMPLETION TIME 7 days 24 hours 6 hours 36 hours SURVEILLANCE REQUIREMENTS - WOG STS 3.7.14-1 Rev. 3.0, 03/31/04 SURVEILLANCE SR 3.7.14.1 Operate each PREACS train for [r 10 continuous hours with heaters operating or (for systems without heaters) 2 15 minutes].
FREQUENCY
--,.-.., PREACS 3.7.14 3.7 PLANT SYSTEMS 3.7.14 Penetration Room Exhaust Air Cleanup System (PREACS)LCO 3.7.14 APPLICABILITY:
ACTIONS Two PREACS trains shall be OPERABLE.--------------------------------------------
NOTE-------------------------------------------
The penetration room boundary may be opened intermittently under administrative control.MODES 1, 2, 3, and 4.CONDITION REQUIRED ACTION COMPLETION TIME A.One PREACS train A.1 Restore PREACS train to 7 days inoperable.
OPERABLE status.B.Two PREACS trains B.1 Restore penetration room 24 hours inoperable due to boundary to OPERABLE inoperable penetration status.room boundary.C.Required Action and C.1 Be in MODE 3.6 hours associated Completion Time not met.AND C.2 Be in MODE 5.36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY_.__._-_._-----------------------+--------
SR 3.7.14.1 WOGSTS Operate each PREACS train for[2: 10 continuous f31hours with heaters operating or (for systems without L::'....
..heaters)::::
15 minutes].,u3.7.14-1 Rev.3.0, 03/31/04 PREACS 3.7.14 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE SR 3.7.14.2 Perform required PREACS filter testing in accordance with the [Ventilation Filter Testing Program (VFTP)]. SR 3.7.14.3
['Verify each PREACS train actuates on an actual or simulated actuation signal.
SR 3.7.14.4 [ Verify one PREACS train can maintain a pressure 5 [-0.1251 inches water gauge relative to atmospheric pressure during the [post accident]
mode of operation at a flow rate of S [3000] cfm. SR 3.7.14.5 [ Verify each PREACS filter bypass damper can be closed. WOG STS FREQUENCY In accordance with the [VFTP] - [I81 months on a STAGGERED TEST BASIS-] I [I 81 months " ] Rev. 3.0, 03/31/04 SURVEILLANCE PREACS 3.7.14 FREQUENCY SR 3.7.14.2 SR 3.7.14.3 SR 3.7.14.4 SR 3.7.14.5 WOG STS Perform required PREACS filter testing in accordance with the[Ventilation Filter Testing Program (VFTP)).[Verify each PREACS train actuates on an actual or simulated actuation signal.[Verify one PREACS train can maintain a pressure[-0.125]inches water gauge relative to atmospheric pressure during the[post accident]mode of operation at a flow rate of:S;[3000J cfm.[Verify each PREACS filter bypass damper can be closed.3.7.14-2 In accordance with the[VFTP]Rev.3.0, 03/31/04 Fuel Storage Pool Water Level 3.7.15 3.7 PLANT SYSTEMS 3.7.15 Fuel Storage Pool Water Level LC0 3.7.15 The fuel storage pool water level shall be 2 23 ft over the top of irradiated fuel assemblies seated in the storage racks.
APPLICABILITY:
During movement of irradiated fuel assemblies in the fuel storage pool.
ACTIONS CONDITION A. Fuel storage pool water level not within limit.
REQUIRED ACTION COMPLETION TIME A. 1 --------------
NOTE --------------
LC0 3.0.3 is not applicable.
-------------------+------------d---- Suspend movement of irradiated fuel assemblies in the fuel storage pool. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.15.1 seated in the storage racks.
WOG STS Rev. 3.0, 03/31/04 Fuel Storage Pool Water Level 3.7.15 3.7 PLANT SYSTEMS 3.7.15 Fuel Storage Pool Water Level LCO 3.7.15 APPLICABILITY:
ACTIONS The fuel storage pool water level shall be23 ft over the top of irradiated fuel assemblies seated in the storage racks.During movement of irradiated fuel assemblies in the fuel storage pool.CONDITION A.Fuel storage pool water A.1 level not within limit.REQUIRED ACTION--------------N 0 TE--------------
LCO 3.0.3 is not applicable.
COMPLETION TIME SURVEILLANCE REQUIREMENTS Suspend movement of Immediately irradiated fuel assemblies in the fuel storage pool.SR 3.7.15.1 WOGSTS SURVEILLANCE Verify the fuel storage pool water level is23 ft abovethetop of the irradiated fuel assemblies seated in the storage racks.3.7.15-1 FREQUENCY Rev.3.0, 03/31/04
[Fuel Storage Pool Boron Concentration]
3.7.16 SURVEILLANCE REQUIREMENTS SURVEILLANCE I FREQUENCY SR 3.7.16.1 Verify the fuel storage pool boron concentration is within limit.
WOG STS Rev. 3.0, 03131104 [Fuel Storage Pool Boron Concentration]
3.7.16 SURVEILLANCE REQUIREMENTS SR 3.7.16,1 WOGSTS SURVEILLANCE Verify the fuel storage pool boron concentration is within limit.3.7.16-2 FREQUENCY Rev.3.0, 03/31/04 Secondary Specific Activity 3.7.18 3.7 PLANT SYSTEMS 3.7.1 8 Secondary Specific Activity LC0 3.7.18 The specific activity of the secondary coolant shall be 5 [0.10] pCi/gm DOSE EQUIVALENT 1-1 31. APPLICABILITY:
MODES 1, 2, 3, and 4. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Specific activity not within limit. A.l Be in MODE 3. AND A.2 Be in MODE 5. 6 hours 36 hours SURVEILLANCE REQUIREMENTS WOG STS Rev. 3.0, 03/31/04 Secondary Specific Activity 3.7.18 3.7 PLANT SYSTEMS 3.7.18 Secondary Specific Activity LCO 3.7.18 APPLICABILITY:
ACTIONS The specific activity of the secondary coolant shall be:;;[0.1 0]
DOSE EQUIVALENT 1-131.MODES 1, 2, 3, and 4.CONDITION A.Specific activity not within limit.A.1 A.2 REQUIRED ACTION Be in MODE 3.Be in MODE 5.COMPLETION TIME 6 hours 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.18.1 WOGSTS Verify the specific activity of the secondary coolant is:;;[0.10)
DOSE EQUIVALENT 1-131.3.7.18-1 Rev.3.0, 03/31/04 AC Sources - Operating
 
====3.8.1 ACTIONS====
(continued)
CONDITION -----REVIEWER'S NOTE-----
This Condition may be deleted if the unit design is such that any sequencer failure mode will only affect the ability of the associated DG to power its respective safety loads following a loss of offsite power independent of, or coincident with, a Design Basis Event.
-------+*--------------dm-------------
F. [ One [required]
[automatic load sequencer] inoperable.
G. Required Action and associated Completion Time of Condition A, B, C, D, E, or [F] not met. H. Three or more [required]
AC sources inoperable,. REQUIRED ACTION F.l Restore [required]
[automatic load sequencer]
to OPERABLE status.
G.l Be in MODE 3. AND G.2 Be in MODE 5. H.1 Enter LC0 3.0.3. COMPLETION TIME [I 21 hours ] -- 6 hours 36 hours Immediately GURVEILLANCE I FREQUENCY SR 3.8.1.1 Verify dorrect breaker alignment and indicated power availability for each [required]
offsite circuit. WOG STS Rev. 3.1, 12/01 /O5 AC Sources-Operating 3.8.1 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME-----REVIEWER'S NOTE-----F.1 Restore[required]
[12]hours]This Condition may be[automatic load sequencer]
deleted if the unit design is to OPERABLE status.such that any sequencer failure mode will only affect the ability of the associated DG to power its respective safety loads following a loss of offsite power independent of, or coincident with, a Design Basis Event.------_..........
------------_
..._-------------
F.[One[required]
[automatic load sequencer]
inoperable.
,-...,.G.Required Action and G.1 Be in MODE 3.6 hours associated Completion Time of Condition A, B, AND C, D, E, or[F]not met.G.2 Be in MODE 5.36 hours H.Three or more[required]
H.1 Enter LCO 3.0.3.Immediately AC sources inoperable,.
!SURVEILLANCE REQUIREMENTS SR 3.8.1.1 WOG STS I SURVEILLANCE Verify dorrect breaker alignment and indicated power availability for each[required]
offsite circuit.3.8.1-4 FREQUENCY Rev.3.1, 12/01/05 AC Sources - Operating SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE SR 3.8.1.2 ------------------------------NOTES
.............................
: 1. All DG starts may be preceded by an engine prelube period and followed by a warmup period prior to loading. [ 2. A modified DG start involving idling and gradual acceleration to synchronous speed may be used for this SR as recommended by the manufacturer. When modified start procedures are not used, the time, voltage, and frequency tolerances of SR 3.8.1.7 must be met. ] -----------**-----------------------------*------------------------- Verify each DG starts from standby conditions and achieves steady state voltage r [3740] V and 5 [4580] V, and frequency 2 [58.8] Hz and 5 [61.2] Hz. 2. Momentary transients outside the load range do not invalidate this test.
: 3. This Surveillance shall be conducted on only one DG at a time. 4. This SR shall be preceded by and immediately follow without shutdown a successful performance of SR 3.8.1.2 or SR 3.8.1.7. Verify each DG is synchronized and loaded and operates for 2 60 minutes at a load 2 [4500] kW and 5 [5000] kW. SR 3.8.1.4 Verify each day tank [and engine mounted tank]
contains 2 [220] gal of fuel oil.
WOE STS FREQUENCY
& days h 31 days Rev. 3.1, l2/Ol/O5 AC Sources-Operating 3.8.1 SURVEILLANCE FREQUENCY SR 3.8.1.2------------------------------NOTES-----------------------------
1.All DG starts may be preceded by an engine prelube period and followed by a warmup period prior to loading.[2.A modified DG start involving idling and gradual acceleration to synchronous speed may be used for this SR as recommended by the manufacturer.
When modified start procedures are not used, the time, voltage, and frequency tolerances of SR 3.8.1.7 must be met.J Verify each DG starts from standby conditions and achieves steady state voltage[3740]Vand S[4580]V, and frequency[58.8]Hz and S[61.2]Hz.Edays SR 3.8.1.3------------------------------
NOTES-----------------------------
1.DG loadings may include gradual loading as recommended by the manufacturer.
2.Momentary transients outside the load range do not invalidate this test.3.This Surveillance shall be conducted on only one DG at a time.4.This SR shall be preceded by and immediately follow without shutdown a successful performance of SR 3.8.1.2 or SR 3.8.1.7.Verify each DG is synchronized and loaded and operates for60 minutes at a load[4500]kW and S[5000]kW.SR 3.8.1.4 f31 days?-t.:
Verify each day tank[and engine mounted tank]§days?_______
_fu_e_1 O_i_1.
__
WOGSTS 3.8.1-5 Rev.3.1,12/01/05 AC Sources - Operating
 
====3.8.1 SURVEILLANCE====
REQUIREMENTS (continued)
SURVEILLANCE SR 3.8.1.5 Check for and remove accumulated water from each day tank [and engine mounted tank]. SR 3.8.1.6 Verify the fuel oil transfer system operates to [automatically] transfer fuel oil from storage tank[s] to the day tank [and engine mounted tank].
SR 3.8.1.7 ----------------------*-------
NOTE ...............................
All DG starts may be preceded by an engine prelube period. Verify each DG starts from standby condition and achieves:
: a. In 5 [lo] seconds, voltage 2 [3740] V and frequency 2 58.83 Hz and b. Steady state voltage 2 [3740] V and 5 [4580] V, and frequency 2 [58.8] Hz and 5 [61.2] Hz. SR 3.8.1.8 ..............................
NOTE ...............................
[ This Surveillance shall not normally be performed in MODE 1 or 2. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. ---------------------------*----------*------------------------------
Verify [automatic [and] manual] transfer of AC power sources from the normal offsite circuit to each alternate [required]
offsite circuit. FREQUENCY 64 days - L WOG STS Rev. 3.1, 12/01/05 SURVEILLANCE AC Sources-Operating 3.8.1 FREQUENCY SR 3.8.1.5 Check for and remove accumulated water from each day tank[and engine mounted tank].SR 3.8.1.6 SR 3.8.1.7 Verify the fuel oil transfer system operates to@2]days[automatically]
transfer fuel oil from storage tank[s]to the day tank[and engine mounted tank].------------------------------
NOTE-------------------------------
All DG starts may be preceded by an engine prelube period.SR 3.8.1.8 Verify each DG starts from standby condition and achieves: a.In S[10]seconds, voltage;::=[3740]V and frequency;::=
58.8J Hz and b.Steady state voltage[3740]V and s[4580]V, and frequency;::=
[58.8J Hz and S[61.2J Hz.------------------------------
NOT E-------------------------------
[This Surveillance shall not normally be performed in MODE 1 or 2.However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Credit may be taken for unplanned events that satisfy this SR Verify[automatic
[and]manual]transfer of AC power (ITS]months]sources from the normal offsite circuit to each alternate[required]
offsite circuit.WOGSTS 3.8.1-6 Rev.3.1,12/01/05 AC Sources - Operating SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE SR 3.8.1.9 ------------------------------NOTES
.............................
[I. This Surveillance shall not normally be performed in MODE 1 or 2. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. 2. If performed with the DG synchronized with offsite power, it shall be performed at a power factor 5 [0.9]. However, if grid conditions do not permit, the power factor limit is not required to be met. Under this condition the power factor shall be maintained as close to the limit as practicable.
] ------++------------------------------------++----------------------- Verify each DG rejects a load greater than or equal to its associated single largest post-accident load, and: a. Following load rejection, the frequency is 2 [63] Hz, b. Within [3] seconds following load rejection, the voltage is 2 [3740] V and I [4580] V, and G. Within [3] seconds following load rejection, the frequency is 2 [58.8] Hz and 2 [61.2] Hz. FREQUENCY
/ [I81 months 6 WOG STS Rev. 3.1, 12/01/05 SURVEILLANCE AC Sources-Operating 3.8.1 FREQUENCY SR 3.8.1.9 WOGSTS------------------------------NOTES-----------------------------
[1.This Surveillance shall not normally be performed in MODE 1 or 2.However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Credit may betaken for unplanned events that satisfy this SR.2.If performed with the DG synchronized with offsite power, it shall be performed at a power factor:S;[0.9J.However, if grid conditions do not permit, the power factor limit is not required to be met.Under this condition the power factor shall be maintained as close to the limit as practicable.
J Verify each DG rejects a load greater than or equal to its associated single largest post-accident load.and: a.Following load rejection, the frequency is:5[63J Hz, b.Within[3J seconds follOWing load rejection, the voltage is[3740}V and:5[4580}V, and c.Within[3]seconds following load rejection, the frequency is[58.8J Hz and:5[61.2J Hz.3.8.1-7[f8]months InSert 1 Rev.3.1,12101/05 AC Sources - Operating SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE SR 3.8.1.10 ..............................
NOTES .............................
[ 1. This Surveillance shall not normally be performed in MODE I or 2. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. 2. If performed with DG synchronized with offsite power, it shall be performed at a power factor 5 10.91. However, if grid conditions do not permit, the power factor limit is not required to be met. Under this condition the power factor shall be maintained as close to the limit as practicable.
] Verify each DG does not trip and voltage is maintained 5 [5000] V during and following a load rejection of 2 [4500] kW and 5 [5000] kW. WOG STS FREQUENCY - [I%] months Rev. 3.1. 12101105 SURVEILLANCE AC Sources-Operating 3.8.1 FREQUENCY SR 3.8.1.10 WOGSTS------------------------------NOTES-----------------------------
[1.This Surveillance shall not normally be performed in MODE 1 or 2.However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Credit may be taken for unplanned events that satisfy this SR.2.If performed with DG synchronized with offsite power, it shall be performed at a power factor::;{O.g].However, if grid conditions do not permit, the power factor limit is not required to be met.Under this condition the power factor shall be maintained as close to the limit aspracticable.]
Verify each DG does not trip and voltage is maintained::;
[5000]V during and following a load rejection of[4500]kW and:5[5000]kW.3.8.1-8@:B1months(ir\5e r!})Rev.3.1, 12/01/05 AC Sources - Operating SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE
: 2. This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.
Credit may be taken for unplanned events that satisfy this SR. .....................................................................
Verify on an actual or simulated loss of offsite power signal: a. De-energization of emergency buses, b. Load shedding from emergency buses, c. DG auto-starts from standby condition and: 1 Energizes permanently connected loads in 5 [lo] seconds, 2. Energizes auto-connected shutdown loads through
[automatic load sequencer], 3. Maintains steady state voltage, 2 [3740] V and s 1.15801 V, 4. Maintains steady state frequency 2 [58.8] Hz and 5 [61.2] Hz, and 5. Supplies permanently connected [and auto-connected] shutdown loads for 2 5 minutes. FREQUENCY
[I 81 months - WOG STS Rev. 3.1, 12/01/05 SURVEILLANCE AC Sources-Operating 3.8.1 FREQUENCY SR 3.8.1.11 WOGSTS------*-----------------------NOTES---------------
***-----------
1.All DG starts may be preceded by an engine prelube period.2.This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4.However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Credit may be taken for unplanned events that satisfy this SR.Verify on an actual or simulated loss of offsite power signal: a.De-energization of emergency buses, b.Load shedding from emergency buses, c.DG auto-starts from standby condition and: 1.Energizes permanently connected loads in[10]seconds, 2.Energizes auto-connected shutdown loads through[automatic load sequencer], 3.Maintains steady state voltage.[3740]V and[4580]V, 4.Maintains steady state frequency[58.8]Hz and[61.2]Hz, and 5.Suppliespermanentlyconnected
[and auto-connected]
shutdown loads for5 minutes.3.8.1-9 Rev.3.1, 12/01/05 AC Sources - Operating SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE
: 2. This Surveillance shall not normally be performed in MODE 1 or 2. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. Verify on an actual or simulated Engineered Safety Feature (ESF) actuation signal each DG auto-starts from standby condition and:
: a. In 5 [lo] seconds after auto-start and during tests, achieves voltage r [3740] V and frequency 2 [58.8] Hz, b. Achieves steady state voltage 2 [3740] V and 5 [4580] V and frequency r [58.8] Hz and 5 [61.2] Hz, c. Operates for 2 5 minutes, d. Permanently connected loads remain energized from the offsite power system, and e. Emergency loads are energized
[or auto- connected through the automatic load sequencer] from the offsite power system.
FREQUENCY WOG STS Rev. 3.1, 12/01/05 SURVEILLANCE AC Sources-Operating 3.8.1 FREQUENCY SR 3.8.1.12 WOGSTS--.-.-----*-------------------NOTES----------------------------
[1.All DG starts may be preceded by prelube period.2.This Surveillance shall not normally be performed in MODE 1 or 2.However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Credit may be taken for unplanned events that satisfy this SR.Verify on an actual or simulated Engineered Safety Feature (ESF)actuation signal each DG auto-starts from standby condition and: a.In[10J seconds after auto-start and during tests, achieves voltage;:::
[37401 V and frequency;:::
[58.8]Hz, b.Achieves steady state voltage;:::
[3740J V and::;[4580J V and frequency;:::
[58.8)Hz and[61.2J Hz, c.Operates for;::: 5 minutes, d.Permanently connected loads remain energized from the offsite power system, and e.Emergency loads are energized[orconnected through the automatic load sequencerJ from the offsite power system.3.8.1-10 fEBl month£}Rev.3.1,12/01/05 AC Sources - Operating SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE SR 3.8.1.13 NOTE ...............................
[ This Surveillance shall not normally be performed in MODE 1 or 2. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. ] ---------------------**---------------------------------------------- Verify each DG's noncritical automatic trips are bypassed on [actual or simulated loss of voltage signal on the emergency bus concurrent with an actual or simulated ESF actuation signal]. FREQUENCY
/ [I81 months WOG STS Rev. 3.1, 12/01/05 SURVEILLANCE AC Sources-Operating 3.8.1 FREQUENCY SR 3.8.1.13 WOGSTS------------------------------
NOTE-------------------------------
[This Surveillance shall not normally be performed in MODE 1 or 2.However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Credit may be taken for unplanned events that satisfy this SR.I Verify each DG's noncritical automatic trips are bypassed on[actual or simulated loss of voltage signal on the emergency bus concurrent with an actual or simulated ESF actuation signal].3.8.1-11@l months Rev.3.1,12/01/05 AC Sources - Operating 3.8.1 :QUIREMENTS (continued)
SURVEILLANCE I FREQUENCY SR 3.8.1.14 -----------------------------*
NOTES .............................
I. Momentary transients outside the load and power factor ranges do not invalidate this test.
: 2. This Surveillance shall not normally be performed in MODE 1 or 2. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. 3. If performed with DG synchronized with offsite power, it shall be performed at a power factor 5 [0.9]. However, if grid conditions do not permit, the power factor limit is not required to be met. Under this condition the power factor shall be maintained as close to the limit as practicable. Verify each DG operates for r 24 hours: a. For 2 [2] hours loaded 2 [5250] kW and 5 [5500] kW and b. For the remaining hours of the test loaded r [4500] kW and 5 [5000] kW. WOG STS Rev. 3.1, 12/01/05 SURVEILLANCE AC Sources-Operating 3.8.1 FREQUENCY SR 3.8.1.14 WOGSTS------------------------------NOTES-----------------------------
1.Momentary transients outside the load and power factor ranges do not invalidate this test.2.This Surveillance shall not normally be performed in MODE 1 or 2.However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Credit may be taken for unplanned events that satisfy this SR.3.If performed with DG synchronized with offsite power, it shall be performed at a power factor::;[0.9].However, if grid conditions do not permit, the power factor limit is not required to be met.Under this condition the power factor shall be maintained as close to the limit as practicable.
Verify each DG operates for;;:=24 hours: a.For;;:=[2]hours loaded;;:=[5250]kWand::;[5500]kW and b.For the remaining hours of the test loaded:=::[4500]kW and::;[5000]kW.3.8.1-12 Rev.3.1,12/01/05 AC Sources - Operating SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE SR 3.8.1.15 ----------------------a"-----
NOTES -------------em--------------
I. This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated 2 [2] hours loaded 2 [4500] kW and 5 [5000] kW. Momentary transients outside of load range do not invalidate this test. 2. All DG starts may be preceded by an engine prelube period.
-------------*------------------------------------***+--------------- Verify each DG starts and achieves:
: a. In 5 [lo] seconds, voltage 2 [3740] V and frequency 2 [58.8] Hz and b. Steady state voltage r [3740] V, and 5 [4580] V and frequency 2 [58.8] Hz and S [61.2] Hz. SR 3.8.1.76 --------------------*-++*-----
NOTE ............................... This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. Verify each DG: a. Synchronizes with offsite power source while loaded with emergency loads upon a simulated restoration of offsite power, b. Transfers loads to offsite power source, and
: c. Returns to ready-to-load operation.
WOG STS FREQUENCY months 6 Rev. 3.1, 12/01/05 AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SR 3.8.1.15 SR 3.8.1.16 WOGSTS SURVEILLANCE-----------------------------NOTES-----------------------------
1.This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated;;;:
[2]hours loaded<::[4500]kW and$[5000]kW.Momentary transients outside of load range do not invalidate this test.2.All DG starts may be preceded by an engine prelube period.Verify each DG starts and achieves: a.In:S[10]seconds, voltage<::[3740]V and frequency<::[58.8]Hz and b.Steady state voltage<::[3740]V, and$[45801 V and frequency<::[58.8]Hz and:s;[61.2]Hz.------------------------------
NOT E-------------------------------
This Surveillance shall not normally be performed in tv10DE 1, 2, 3, or 4.However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Credit may be taken for unplanned events that satisfy this SR.Verify each DG: a.Synchronizes with offsite power source while loaded with emergency loads upon a simulated restoration of offsite power, b.Transfers loads to offsite power source, and c.Returns to ready-to-Ioad operation.
3.8.1-13 FREQUENCY[li8]months b Rev.3.1, 12/01/05 AC Sources - Operating SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE SR 3.8.1.17 -------------*----------------
NOTE --------------a*---------------
[ This Surveillance shall not normally be performed in MODE I, 2, 3, or 4. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.
Credit may be taken for unplanned events that satisfy this SR. Verify, with a DG operating in test mode and connected to its bus, an actual or simulated
*SF actuation signal overrides the test mode by: a. Returning DG to ready-to-load operation and
: b. [Automatically energizing the emergency load from offsite power]. SR 3.8.1.18 ------------------------------NOTE
[ This Surveillance shall not normally be performed in MODE I, 2, 3, or 4. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. ] ------------------------------------+-------------------------------- Verify interval between each sequenced load block is within f [lo% of design interval] for each emergency [and shutdown]
load sequencer.
FREQUENCY C [la] months C WOG STS Rev. 3.1, 12/01/05 SURVEILLANCE AC Sources-Operating 3.8.1 FREQUENCY SR 3.8.1.17 SR 3.8.1.18 WOGSTS------------------------------
NOTE-------------------------------
[This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4.However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Credit may be taken for unplanned events that satisfy this SR.Verify, with a DG operating in test mode and connected to its bus, an actual or simulated ESF actuation signal overrides the test mode by: a.Returning DG to ready-to-Ioad operation and b.[Automatically energizing the emergency load from offsite power].------------------------------
NOT E------------------------------
[This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4.However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Credit may be taken for unplanned events that satisfy this SR.J Verify interval between each sequenced load block is within+/-[10%of design interval]for each emergency[and shutdown]load sequencer.
3.8.1-14 Rev.3.1,12/01/05 AC Sources - Operating SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE
: 2. This Surveillance shall not normally be performed in MODE I, 2, 3, or 4. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. ------------------------------------------------*-------w-w-*----dd--
Verify on an actual or simulated loss of offsite power signal in conjunction with an actual or simulated ESF actuation signal: a. De-energization of emergency buses, b. Load shedding from emergency buses, and
: c. DG auto-starts from standby condition and:
I. Energizes permanently connected loads in 5 [I 01 seconds, 2. Energizes auto-connected emergency loads through load sequencer, 3. Achieves steady state voltage r [3740] V and 5 [4580] V, 4. Achieves steady state frequency 2 [58.8] Hz and I [61.2] Hz, and 5. Supplies permanently connected [and auto-connected] emergency loads for 2 5 minutes. WOG STS FREQUENCY 181 months + r Rev. 3.1, 12/01/05 SURVEILLANCE AC Sources-Operating 3.8.1 FREQUENCY SR 3.8.1.19 WOGSTS------------------------------
NOTE S-----------------------------
1.All DG starts may be preceded by an engine prelube period.2.This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4.However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Credit may be taken for unplanned events that satisfy this SR.Verify on an actual or simulated loss of offsite power signal in conjunction with an actual or simulated ESF actuation signal: a.De-energization of emergency buses, b.Load shedding from emergency buses, and c.DG auto-starts from standby condition and: 1.Energizes permanently connected loads in[10]seconds, 2.Energizes auto-connected emergency loads through load sequencer, 3.Achieves steady state voltage[3740]V and[4580]V, 4.Achieves steady state frequency;:::[58.8]Hz and[61.2]Hz, and 5.Supplies permanently connected[and auto-connected]
emergency loads for5 minutes.3.8.1-15 Rev.3.1,12/01/05 AC Sources - Operating SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE Verify when started simultaneously from standby condition, each DG achieves:
: a. In 5 [I 0] seconds, voltage 2 [3740] V and frequency 2 [58.8] Hz and b. Steady state voltage 2 [3744] V and I [4576] V, and frequency 2 [58.8] Hz and I [61.2] Hz. FREQUENCY years WOG STS Rev. 3.1, 12/01/05 SURVEILLANCE AC Sources-Operating 3.8.1 FREQUENCY SR 3.8.1.20 WOG STS------------------------------N 0 TE-------------------------------
All DG starts may be preceded by an engine prelube period.Verify when started simultaneously from standby condition, each DG achieves: a.In::::;[10}seconds, voltage;::.:
[3740}V and frequency 2':[58.8]Hz and b.Steady state voltage;::':
[3744]V and::;[4576]V, and frequency;::':
[58.8J Hz and::;[61.2]Hz.3.8.1-16 Rev.3.1,12/01/05 Diesel Fuel Oil, Lube Oil, and Starting Air
 
====3.8.3 ACTIONS====
(continued)
CONDITION F. Required Action and associated Completion Time not met. One or more DGs with diesel fuel oil, lube oil, or starting air subsystem not within limits for reasons other than Condition A, B, C, D, or E. REQUIRED ACTION 1 COMPLETION TIME inoperable.
F.l Declare associated DG Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.8.3.1 Verify each fuel oil storage tank contains r [33,000] gal of fuel. SR 3.8.3.2 Verify lubricating oil inventory is r [500] gal. SR 3.8.3.3 Verify fuel oil properties of new and stored fuel oil are tested in accordance with, and maintained within the limits of, the Diesel Fuel Oil Testing Program.
SR 3.8.3.4 Verify each DG air start receiver pressure is L [225] psig. SR 3.8.3.5 Check for and remove accumulated water from each fuel oil storage tank.
WOG STS FREQUENCY In accordance with the Diesel Fuel Oil Testing Program Rev. 3.0, 03/31/04 Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 ACTIONS (continued)
CONDITION F.Required Action and associated Completion Time not met.One or more DGs with diesel fuel oil, lube oil, or starting air subsystem not within limits for reasons other than Condition A, B, C, D, or E.F.1 REQUIRED ACTION Declare associated DG inoperable.
COMPLETION TIME Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.3.1 SR 3.8.3.2 SR 3.8.3.3 SR 3.8.3.4 SR 3.8.3.5 WOGSTS Verify each fuel oil storage tank contains;::=[33,000]gal of fuel.Verify lubricating oil inventory is;::=[500]gal.Verify fuel oil properties of new and stored fuel oil are tested in accordance with, and maintained within the limits of, the Diesel Fuel Oil Testing Program.Verify each DG air start receiver pressure is;::=[225]psig.Check for and remove accumulated water from each fuel oil storage tank.3.8.3-2 In accordance with the Diesel Fuel Oil Testing Program Rev.3.0, 03/31/04 DC Sources - Operating SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.8.4.1 Verify battery terminal voltage is greater than or equal to the minimum established float voltage. SR 3.8.4.2 Verify each battery charger supplies 2 [400] amps at greater than or equal to the minimum established float voltage for r [8] hours. Verify each battery charger can recharge the battery to the fully charged state within
[24] hours while supplying the largest combined demands of the various continuous steady state loads, after a battery discharge to the bounding design basis event discharge state.
SR 3.8.4.3 NOTES .............................
I. The modified performance discharge test in SR 3.8.6.6 may be performed in lieu of SR 3.8.4.3. 2. This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. Verify battery capacity is adequate to supply, and maintain in OPERABLE status, the required emergency loads for the design duty cycle when subjected to a battery service test.
FREQUENCY 7 days -4 [18] months - .a- [I81 month C WOG STS Rev. 3.0, 03/31/04 DC Sources-Operating 3.8.4 SURVEILLANCE REQUIREMENTS SR 3.8.4.1 SR 3.8.4.2 SR 3.8.4.3 WOGSTS SURVEILLANCE Verify battery terminal voltage is greater than or equal to the minimum established float voltage.Verify each battery charger supplies<::[400]amps at greater than or equal to the minimum established float voltage for<::[8]hours.Verify each battery charger can recharge the battery to the fully charged state within[24]hours while supplying the largest combined demands of the various continuous steady state loads, after a battery discharge to the bounding design basis event discharge state.------------------------------
NOTES-----------------------------
1.The modified performance discharge test in SR 3.8.6.6 may be performed in lieu of SR 3.8.4.3.2.This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4.However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Credit may be taken for unplanned events that satisfy this SR.Verify battery capacity is adequate to supply, and maintain in OPERABLE status, the required emergency loads for the design duty cycle when subjected to a battery service test.3.8.4-2 FREQUENCY08J monthS=:
r[-p J: erID Rev.3.0, 03/31/04 Battery Parameters
 
====3.8.6 ACTIONS====
(continued)
CONDITION I REQUIRED ACTION F. Required Action and F.1 Declare associated battery associated Completion inoperable. Time of Condition A, B, C, D, or E not met. One [or two] batter[y][ies on one train] with one or more battery cells float voltage < [2.07] V and float current
> [2] amps.
COMPLETION TIME Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.8.6.1 NOTE ---------*--------------------
Not required to be met when battery terminal voltage is less than the minimum established float voltage of SR 3.8.4.1. Verify each battery float current is I [2] amps. SR 3.8.6.2 Verify each battery pilot cell voltage is 2 [2.07] V. - SR 3.8.6.3 Verify each battery connected cell electrolyte level is greater than or equal to minimum established design limits.
SR 3.8.6.4 Verify each battery pilot cell temperature is greater than or equal to minimum established design limits.
WOG STS FREQUENCY C 31 days 6 - 31 day -. Rev. 3.0, 03/31/04 Battery Parameters
 
====3.8.6 ACTIONS====
(continued)
CONDITION F.Required Action and associated Completion Time of Condition A, B, C, 0, or E not met.OR'One[or two]batter[y][ies on one train]with one or more battery cells float voltage<[2.07]V and float current>[2]amps.F.1 REQUIRED ACTION Declare associated battery inoperable.
COMPLETION TIME Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.1 SR 3.8.6.2 SR 3.8.6.3-------------------------------
NOT E------------------------------
Not required to be met when battery terminal voltage is lessthanthe minimum established float voltage of SR 3.8.4.1.Verify each battery float current is=::;[2]amps.Verify each battery pilot cell voltage is[2.07]V.Verify each battery connected cell electrolyte level is greater than or equal to minimum established design limits.SR 3.8.6.4 Verify each battery pilot_ce_I_1 t_e_m_p_e_ra_t_ur_e_i_s_
9_re_a_te_r_---'--li_)_d_a._
y s r:._.Q..__..o..:-..1'\than or equal to minimum established design limits.
WOG STS 3.8.6-3 Rev.3.0, 03/31/04 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE Battery Parameters
 
====3.8.6 FREQUENCY====
SR 3.8.6.5 SR 3.8.6.6 WOG STS Verify each battery connected cell voltage is[2.07]V.-------------------------------
NOT E------------------------------
This Surveillance shall not be performed in MODE 1, 2, 3, or 4.However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Credit may be taken for unplanned events that satisfy this SR.Verify battery capacity is[80%]of the manufacturer's rating when subjected to a performance discharge test or a modified performance discharge test.3.8.6-4@2 days"'=)(Insexf 1.)g:5-ti J[[0 months 12 months when battery shows degradation, or has reached[85]%of the expected life with capacity<100%of manufacturer's rating 24 months when battery has reached[85]%of the expected life with capacity100%of manufacturer's rating Rev.3.0, 03/31/04 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE Battery Parameters
 
====3.8.6 FREQUENCY====
SR 3.8.6.5 SR 3.8.6.6 WOG STS Verify each battery connected cell voltage is[2.07]V.-------------------------------
NOT E------------------------------
This Surveillance shall not be performed in MODE 1, 2, 3, or 4.However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Credit may be taken for unplanned events that satisfy this SR.Verify battery capacity is[80%]of the manufacturer's rating when subjected to a performance discharge test or a modified performance discharge test.3.8.6-4@2 days"'=)(Insexf 1.)g:5-ti J[[0 months 12 months when battery shows degradation, or has reached[85]%of the expected life with capacity<100%of manufacturer's rating 24 months when battery has reached[85]%of the expected life with capacity100%of manufacturer's rating Rev.3.0, 03/31/04 Inverters - Operating
 
====3.8.7 ACTIONS====
(continued)
I I CONDITION REQUIRED ACTION 1 COMPLETION TIME B.2 Be in MODE 5. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY WOG STS Rev. 3.0, 03/31/04 ACTIONS (continued)
CONDITION REQUIRED ACTION B.2 Be in MODE 5.SURVEILLANCE REQUIREMENTS SURVEILLANCE Inverters-Operating 3.8.7 COMPLETION TIME 36 hours FREQUENCY SR 3.8.7.1 WOGSTS Verify correct inverter voltage,[frequency], and alignment to required AC vital buses.3.8.7-2 t daySRev.3.0,03/31/04 Inverters - Shutdown 3.8.8 ACTIONS (continued)
CONDITION REQUIRED ACTION A.2.2 Suspend movement of [recently] irradiated fuel assemblies.
A.2.3 Suspend operations involving positive reactivity additions that could result in loss of required SDM or boron concentration.
A.2.4 Initiate action to restore required inverters to OPERABLE status.
COMPLETION TIME lmmediately Immediately lmmediately SURVEILLANCE REQUIREMENTS SURVEILLANCE I FREQUENCY - - -- - SR 3.8.8.1 Verify correct inverter voltage, [frequency,]
and alignments to required AC vital buses. WOG STS Rev. 3.0, 03/31/04 Inverters-Shutdown 3.8.8 ACTIONS (continued)
CONDITION REQUIRED ACTION A.2.2 Suspend movement of[recently}
irradiated fuel assemblies.
COMPLETION TIME Immediately A.2.3 Suspend operations Immediately involving positive reactivity additions that could result in loss of required SDM or boron concentration.
A.2.4 Initiate action to restore required inverters to OPERABLE status.SURVEILLANCE REQUIREMENTS SURVEILLANCE Immediately FREQUENCY SR 3.8.8.1 WOGSTS Verify correct inverter voltage,[frequency,]
and alignments to required AC vital buses.3.8.8-2days"'-::'-__...--_
Rev.3.0,03/31/04 Distribution Systems - Operating
 
====3.8.9 ACTIONS====
(continued)
CONDITION D. Required Action and associated Completion Time not met. E. Two or more electrical power distribution subsystems inoperable that result in a loss of safety function. REQUIRED ACTION D.l Be in MODE 3. AND D.2 Be in MODE 5. E.1 Enter LC0 3.0.3. COMPLETION TIME 6 hours 36 hours Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE I FREQUENCY Verify correct breaker alignments and voltage to [required]
AC, DC, and AC vital bus electrical power distribution subsystems.
WOG STS Rev. 3.1, 12/01/05 Distribution Systems-Operating 3.8.9 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME D.Required Action and 0.1 Be in MODE 3.6 hours associated Completion Time not met.AND 0.2 Be in MODE 5.36 hours E.Two or more electrical E.1 Enter LCO 3.0.3.Immediately power distribution subsystems inoperable that result in a loss of safety function.SURVEILLANCE REQUIREMENTS SR 3.8.9.1 WOGSTS SURVEILLANCE Verify correct breaker alignments and voltage to[required]
AC, DC, and AC vital bus electrical power distribution subsystems.
3.8.9-2 FREQUENCY Rev.3.1, 12101/05 Distribution Systems - Shutdown 3.8.1 0 ACTIONS (continued)
CONDITION REQUIRED ACTION A.2.4 Initiate actions to restore required AC, DC, and AC vital bus electrical power distribution subsystems to OPERABLE status. A.2.5 Declare associated required residual heat removal subsystem(s) inoperable and not in operation.
COMPLETION TIME Immediately Immediately SURVEILLANCE REQUIREMENTS SR 3.8.10.1 Verify correct breaker alignments and voltage to days required AC, DC, and AC vital bus electrical power distribution subsystems.
WOG STS Rev. 3.0, 03/31/04 Distribution Systems-Shutdown 3.8.10 ACTIONS (continued)
CONDITION REQUIRED ACTION A.2.4 Initiate actions to restore required AC, DC, and AC vital bus electrical power distribution subsystems to OPERABLE status.A.2.5 Declare associated required residual heat removal subsystem(s) inoperable and not in operation.
SURVEILLANCE REQUIREMENTS SURVEILLANCE COMPLETION TIME Immediately Immediately FREQUENCY SR 3.8.10.1 WOGSTS Verify correct breaker alignments and voltage todays
..._"".
required AC, DC, and AC vital bus electrical power , I::'*"l distribution subsystems.
3.8.10-2 Rev.3.0, 03/31/04 Boron Concentration 3.9.1 3.9 REF 3.9.1 UELING OPERATIONS Boron Concentration LC0 3.9.1 APPLICABILITY: Boron concentrations of the Reactor Coolant System, the refueling canal, and the refueling cavity shall be maintained within the limit specified in the COLR. MODE 6. -----------------**--------------------------
NOTE ........................................... Only applicable to the refueling canal and refueling cavity when connected to the RCS. ACTIONS CONDITION A. Boron concentration not within limit. REQUIRED ACTION A.l Suspend CORE ALTERATIONS.
A.2 Suspend positive reactivity additions.
A.3 Initiate action to restore boron concentration to within limit.
COMPLETION TIME Immediately Immediately Immediately SURVEILLANCE REQUIREMENTS - SURVEILLANCE I FREQUENCY SR 3.9.1.1 Verify boron concentration is within the limit specified in the COLR. WOG STS 3.9.1-1 Rev. 3.0, 03/31/04 Boron Concentration 3.9.1 3.9 REFUELING OPERATIONS
 
====3.9.1 Boron====
Concentration LCO 3.9.1 Boron concentrations of the Reactor Coolant System, the refueling canal, and the refueling cavity shall be maintained within the limit specified in the COLR.APPLICABILITY:
ACTIONS MODE 6.
0 TE--------------------------------------------
Only applicable to the refueling canal and refueling cavity when connected to the RCS.CONDITION A.Boron concentration not A.1 within limit.AND A.2 A.3 SURVEILLANCE REQUIREMENTS REQUIRED ACTION Suspend CORE ALTERATIONS.
Suspend positive reactivity additions.
Initiate action to restore boron concentration to within limit.COMPLETION TIME Immediately Immediately Immediately SR 3.9.1.1 WOGSTS SURVEILLANCE Verify boron concentration is within the limit specified in the COLR.3.9.1-1 FREQUENCY
_In5erEI)Rev.3.0, 03/31/04
[Unborated Water Source Isolation Valves) 3.9.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.2.1 Verify each valve that isolates unborated water sources is secured in the closed position.
WOG STS Rev. 3.0, 03131104 [Un borated Water Source Isolation Valves}3.9.2 SURVEILLANCE REQUIREMENTS SR 3.9.2.1 WOG STS SURVEILLANCE Verify each valve that isolates unborated water sources is secured in the closed position.3.9.2-2 FREQUENCY Insertf Rev.3.0, 03/31/04 Nuclear Instrumentation
 
====3.9.3 ACTIONS====
(continued)
CONDITION
-----REVIEWER'S NOTE-----
Condition C is included only for plants that assume a boron dilution event is mitigated by operator response to an audible source range indication.
......................................
C. [ Required source range audible [alarm] [count rate] circuit inoperable.
REQUIRED ACTION C.l Initiate action to isolate unborated water sources.
COMPLETION TIME Immediately
] SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.3.1 Perform CHANNEL CHECK. Perform CHANNEL CALIBRATION.
WOG STS Rev. 3.0, 03/31/04 Nuclear Instrumentation
 
====3.9.3 ACTIONS====
(continued)
CONDITION-----REVIEWER'S NOTE-----C.1 Condition C is included only for plants that assume a boron dilution event is mitigated by operator response to an audible source range indication.
C.[Required source range audible[alarm][count rate]circuit inoperable.
SURVEILLANCE REQUIREMENTS REQUIRED ACTION Initiate action to isolate unborated water sources.COMPLETION TIME Immediately]
SR 3.9.3.1 SR 3.9.3.2 WOGSTS SURVEILLANCE Perform CHANNEL CHECK.-------------------------------
NOT E------------------------------
Neutron detectors are excluded from CHANNEL CALIBRATION.
Perform CHANNEL CALIBRATION.
3,9.3-2 FREQUENCY Rev.3.0, 03/31/04 Containment Penetrations
 
====3.9.4 SURVEILLANCE====
REQUIREMENTS SURVEILLANCE SR 3.9.4.1 Verify each required containment penetration is in the required status.
Verify each required containment purge and exhaust valve actuates to the isolation position on an actual or simulated actuation signal. FREQUENCY 681 months + WOG STS Rev. 3.0, 03/31/04 Containment Penetrations
 
====3.9.4 SURVEILLANCE====
REQUIREMENTS SR 3.9.4.1 SR 3.9.4.2 WOG STS SURVEILLANCE Verify each required containment penetration is in the required status.-------------------------------
NOT E------------------------------
Not required to be met for containment purge and exhaust valve(s)in penetrations closed to comply with LCO 3.9.4.c.1.
Verify each required containment purge and exhaust valve actuates to the isolation position on an actual or simulated actuation signal.3.9.4-2 FREQUENCY Rev.3.0, 03/31/04 RHR and Coolant Circulation - High Water Level ACTIONS (continued)
CONDITION REQUIRED ACTION A.4 Close equipment hatch and secure with [four] bolts.
A.5 ' Close one door in each air lock. A.6.1 Close each penetration providing direct access from the containment atmosphere to the outside atmosphere with a manual or automatic isolation valve, blind flange, or equivalent.
A.6.2 Verify each penetration is capable of being closed by an OPERABLE Containment Purge and Exhaust Isolation System. COMPLETION TIME 4 hours 4 hours 4 hours 4 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.9.5.1 Verify one RHR loop is in operation and circulating reactor coolant at a flow rate of 2 [2800] gpm. WOE STS FREQUENCY 6 hours f-\ Rev. 3.0, 03/31/04 ACTIONS (continued)
CONDITION RHR and Coolant Circulation
-High Water Level 3.9.5 REQUIRED ACTION COMPLETION TIME A.4 Close equipment hatch and 4 hours secure with[four]bolts.A.5.Close one door in each air lock.4 hours A.6.1 Close each penetration 4 hours providing direct access from the containment atmosphere to the outside atmosphere with a manual or automatic isolation valve, blind flange, or equivalent.
A.6.2 Verify each penetration is capable of being closed by an OPERABLE Containment Purge and Exhaust (soration System.SURVEILLANCE REQUIREMENTS SURVEILLANCE 4 hours FREQUENCY SR 3.9.5.1 WOGSTS Verify one RHR loop is in operation and circulating reactor coolant at a flow rate of[2800]gpm.3.9.5-2 Rev.3.0, 03/31/04 RHR and Coolant Circulation - Low Water Level 3.9.6 ACTIONS (continued)
CONDITION REQUIRED ACTION B.5.2 Verify each penetration is capable of being closed by an OPERABLE Containment Purge and Exhaust Isolation System.
COMPLETION TIME 4 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE I FREQUENCY SR 3.9.6.1 Verify one RHR loop is in operation and circulating reactor coolant at a flow rate of r [2800] gpm. WOG STS SR 3.9.6.2 Verify correct breaker alignment and indicated power available to the required RHR pump that is not in operation.
Rev. 3.0, 03/31/04 *:I RHR and Coolant Circulation
-Low Water Level 3.9.6 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME B.5.2 Verify each penetration is capable of being closed by an OPERABLE Containment Purge and Exhaust Isolation System.4 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY Verify correct breaker alignment and indicated power available to the required RHR pump that is not in operation.
Verify one RHR loop is in operation and circulating reactor coolant at a flow rate of 2=[2800]gpm.SR 3.9.6.2 SR 3.9.6.1@hours.__*(Inse r 1V EdaysWOGSTS 3.9.6-3 Rev.3.0, 03/31/04 Refueling Cavity Water Level 3.9.7 3.9 REFUELING OPERATIONS
 
====3.9.7 Refueling====
Cavity Water Level LC0 3.9.7 Refueling cavity water level shall be maintained 2 23 ft above the top of reactor vessel flange. APPLICABILITY: During movement of irradiated fuel assemblies within containment.
ACTIONS CONDITION REQUIRED ACTION I COMPLETION TIME SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY A. Refueling cavity water level not within limit.
SR 3.9.7.1 the top of reactor vessel flange.
WOG STS A.l Suspend movement of irradiated fuel assemblies within containment.
Rev. 3.0, 03/31/04 Immediately Refueling Cavity Water Level 3.9.7 3.9 REFUELING OPERATIONS
 
====3.9.7 Refueling====
Cavity Water Level LCO 3.9.7 Refueling cavity water level shall be maintained;:::
23 ft above the top of reactor vessel flange.APPLICABILITY:
ACTIONS During movement of irradiated fuel assemblies within containment.
CONDITION A.Refueling cavity water level not within limit.A.1 REQUIRED ACTION Suspend movement of irradiated fuel assemblies within containment.
COMPLETION TIME Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.7.1 WOGSTS Verify refueling cavity water level is;::: 23 ft abovethetop of reactor vessel flange.3.9.7-1 Rev.3.0, 03/31/04 Programs and Manuals 5.5 5.5 Programs and Manuals
-- 5.5.16 Containment Leakaqe Rate Testinq Program (continued)
: 1. Containment leakage rate acceptance criterion is 2 I .O I,. During the first unit startup following testing in accordance with this program, the leakage rate acceptance criteria are
< 0.60 La for the Type B and C tests and
[< 0.75 L, for Option A Type A tests]
[s 0.75 La for Option B Type A tests]. 2. Air lock testing acceptance criteria are: a) Overall air lock leakage rate is 5 [0.05 La] when tested at 2 Pa. b) For each door, leakage rate is 5 [0.01 La] when pressurized to
[2 10 psig]. e. The provisions of SR 3.0.3 are applicable to the Containment Leakage Rate Testing Program.
: f. Nothing in these Technical Specifications shall be construed to modify the testing Frequencies required by 10 CFR 50, Appendix J. 5.5.17 Batterv Monitorinu and Maintenance Proaram This Program provides for battery restoration and maintenance, based on [the recommendations of IEEE Standard 450-1995, "IEEE Recommended Practice for Maintenance, Testing, and Replacement of Vented Lead-Acid Batteries for Stationary Applications," or of the battery manufacturer] including the following:
: a. Actions to restore battery cells with float voltage i [2.13] V, and b. Actions to equalize and test battery cells that had been discovered with -+ electrolyte level below the minimum established design limit.
WOG STS Rev. 3.1, 12/01/05 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.16 Containment Leakage Rate Testing Program (continued) 1.Containment leakage rate acceptance criterion is=:;1.0 La.During the first unit startup following testing in accordance with this program, the leakage rate acceptance criteria are<0.60 La for the Type Band C tests and[<0.75 La for Option A Type A tests][=:;0.75 La for Option B Type A tests].2.Air lock testing acceptance criteria are: a)Overall air Jock leakage rate is=:;[0.05 LaJ when tested at 2: P a.b)For each door, leakage rate is=:;[0.01 LaJ when pressurized to[G 10 psigJ.e.The provisions of SR 3.0.3 are applicable to the Containment Leakage Rate Testing Program.f.Nothing in these Technical Specifications shall be construed to modify the testing Frequencies required by 10 CFR 50, Appendix J.5.5.17 Battery Monitoring and Maintenance Program This Program provides for battery restoration and maintenance, based on[the recommendations of IEEE Standard 450-1995,"IEEE Recommended Practice for Maintenance, Testing, and Replacement of Vented Batteries for Stationary Applications," or of the battery manufacturerJ including the following:
a.b.Actions to restore battery cells with float voltage<[2.13J V, and Actions to equalize and test battery cells that had been discovered with electrolyte level below the minimum established design limit.WOGSTS 5.5-18 Rev.3.1,12/01/05 SDM B 3.1.1 BASES SURVEILLANCE SR 3.1 .I .I REQUIREMENTS In MODES 1 and 2 with Keff 2 1 .O, SDM is verified by observing that the requirements of LC0 3.1.5 and LC0 3.1.6 are met. In the event that a rod is known to be untrippable, however, SDM verification must account for the worth of the untrippable rod as well as another rod of maximum worth. In MODES 3, 4, and 5, the SDM is verified by performing a reactivity balance calculation, considering the listed reactivity effects:
: a. RCS boron concentration, b. Control bank position, c. RCS average temperature, d. Fuel burnup based on gross thermal energy generation, e. Xenon concentration, f. Samarium concentration. and
: g. Isothermal temperature coefficient (ITC). Using the ITC accounts for Doppler reactivity in this calculation because the reactor is subcritical, and the fuel temperature will be changing at the same rate as the RCS. Ehe Frequency of 24 hours is based on the generally slow change in required boron concentration and the low probability of an accident occurring without the required SDM. This allows time for the operator to collect the required data, which includes performing a boron concentration analysis, and complete the calculation.
6 REFERENCES
: 1. 10 CFR 50, Appendix A, GDC 26. 2. FSAR, Chapter [15]. 3. FSAR, Chapter [15]. 4. 10 CFR 100. WOG STS Rev. 3.0, 03/31/04 BASES SURVEILLANCE REQUIREMENTS REFERENCES SDM B 3.1.1 SR 3.1.1.1 In MODES 1 and 2 with Kef!;::: 1.0, SDM is verified by observing that the requirements of LCO 3.1.5 and LCO 3.1.6 are met.In the event that a rod is known to be untrippable, however, SDM verification must account for the worth of the untrippable rod as well as another rod of maximum worth.In MODES 3,4, and 5, the SDM is verified by performing a reactivity balance calculation, considering the listed reactivity effects: a.RCS boron concentration, b.Control bank position, c.RCS average temperature, d.Fuel burnup based on gross thermal energy generation, e.Xenon concentration, f.Samarium concentration, and g.Isothermal temperature coefficient (ITC).Using the ITC accounts for Doppler reactivity in this calculation because the reactor is subcritical, and the fuel temperature will be changing at the same rate as the RCS.[he Frequency of 24 hours is based on the generally slow change in required boron concentration and the low probability of an accident occurring without the required SDM.This allows time for the operator to collect the required data, which includes performing a boron concentration analysis, and complete the calculation.
1.10 CFR 50, Appendix A, GDC 26.2.FSAR, Chapter[15].3.FSAR, Chapter[15].4.10 CFR 100.WOGSTS B 3.1.1-5 Rev.3.0, 03/31/04 Core Reactivity B 3.1.2 BASES ACTIONS (continued) If the core reactivity cannot be restored to within the 1% Auk limit, the plant must be brought to a MODE in which the LC0 does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 6 hours. If the SDM for MODE 3 is not met, then the boration required by SR 3.1 .l. 1 would occur. 'The allowed Completion Time is reasonable, based on operating experience, for reaching MODE 3 from full power conditions in an orderly manner and without challenging plant systems.
SURVEILLANCE SR 3.1.2.1 REQUIREMENTS Core reactivity is verified by periodic comparisons of measured and predicted RCS boron concentrations.
The comparison is made, considering that other core conditions are fixed or stable, including control rod position, moderator temperature, fuel temperature, fuel depletion, xenon concentration, and samarium concentration. The Surveillance is performed prior to entering MODE I as an initial check on core conditions and design calculations at BOC. The SR is modified by a Note. The Note indicates that the normalization of predicted core reactivity to the measured value must take place within the first 60 effective full power days (EFPD) after each fuel loading. This allows sufficient time for core conditions to reach steady state, but prevents operation for a large fraction of the f el cycle without establishing a benchmark for the design calculations. The required subsequent Frequency of 31 EFPD, following the initial 60 & D after entering MODE 1, is acceptable, based on the slow rate of core changes due to fuel depletion and the presence of other indicators (QPTR, AFD, etc.) for prompt indication of an'anornaly.
& . J REFERENCES
: 1. 10 CFR 50, Appendix A, GDC 26, GDC 28, and GDC 29. @s& 2) 2. FSAR. Cha~ter r151. WOG Rev. 3.0, 03/31/04 Core Reactivity B 3.1.2 BASES ACTIONS (continued)
If the core reactivity cannot be restored to within the 1%Aklk limit, the plant must be brought to a MODE in which the LCO does not apply.To achieve this status, the plant must be brought to at least MODE 3 within 6 hours.If the SDM for MODE 3 is not met, then the boration required by SR 3.1.1.1 would occur.The allowed Completion Time is reasonable, based on operating experience, for reaching MODE 3 from full power conditions in an orderly manner and without challenging plant systems.SURVEILLANCE REQUIREMENTS REFERENCES SR 3.1.2.1 Core reactivity is verified by periodic comparisons of measured and predicted RCS boron concentrations.
The comparison is made, considering that other core conditions are fixed or stable, including control rod position, moderator temperature, fuel temperature, fuel depletion, xenon concentration, and samarium concentration.
The Surveillance is performed prior to entering MODE 1 as an initial check on core conditions and design calculations at BOC.The SR is modified by a Note.The Note indicates that the normalization of predicted core reactivity to the measured value must take place within the first 60 effective full power days (EFPD)after each fuel loading.This allows sufficient time for core conditions to reach steady state, but prevents operation for a large fraction of cycle without establishing a benchmark for the design calculations.
The required subsequent Frequency of 31 EFPD, following the initial 60 D after entering MODE 1, is acceptable, based on the slow rate of core changes due to fuel depletion and the presence of other indicators (QPTR, AFD, etc.)for prompt indication of an anomaly.1.10 CFR 50, Appendix A, GDC 26, GDC 28, and GDC 29.2.FSAR, Chapter[15].WaG B 3.1.2-5 Rev.3.0, 03/31/04 Rod Group Alignment Limits B 3.1.4 BASES ACTIONS (continued) increasing the RCS boron concentration to provide negative reactivity, as described in the Bases or LC0 3.1 .I. The required Completion Time of I hour for initiating boration is reasonable, based on the time required for potential xenon redistribution, the low probability of an accident occurring, and the steps required to complete the action. This allows the operator sufficient time to align the required valves and start the boric acid pumps. Boration will continue until the required SDM is restored. If more than one rod is found to be misaligned or becomes misaligned because of bank movement, the unit conditions fall outside of the accident analysis assumptions. Since automatic bank sequencing would continue to cause misalignment, the unit must be brought to a MODE or Condition in which the LC0 requirements are not applicable. To achieve this status, the unit must be brought to at least MODE 2 with Kerf < 1.0 within 6 hours. The allowed Completion Time is reasonable, based on operating experience, for reaching MODE 2 with Keff < 1.0 from full power conditions in an orderly manner and without challenging plant systems.
SURVEILLANCE SR 3.1 A.1 REQUIREMENTS Grimcation that individual rod positions are within alignment limits at a Frequency of 12 hours provides a history that allows the operator to detect a rod that is beginning to deviate from its expected position. The specified Frequency takes into account other rod position information that is continuously available to the operator in the control room, so that during actual rod motion, deviations can immediately be detected. Verifying each control rod is OPERABLE would require that each rod be tripped. However, in MODES I and 2 with Ken 2 1 .O, tripping each control rod would result in radial or axial power tilts, or oscillations. Exercising each individual control rod 6-9 provides increased confidence that all rods continue to be OPERABLE without exceeding the alignment limit, even if they are not regularly tripped. Moving each control rod by 10 steps will not cause radial or axial power tilts, or oscillations, to occur. pi,e 92 day Frequency takes into consideration other information WOG STS B 3.1.4-8 Rev. 3.0, 03/31/04 Rod Group Alignment Limits B 3.1.4 BASES ACTIONS (continued) increasing the ReS boron concentration to provide negative reactivity, as described in the Bases or LCO 3.1.1.The required Completion Time of 1 hour for initiating boration is reasonable, based on the time required for potential xenon redistribution, the low probability of an accident occurring, and the steps required to complete the action.This allows the operator sufficient time to align the required valves and start the boric acid pumps.Boration will continue until the required SDM is restored.If more than one rod is found to be misaligned or becomes misaligned because of bank movement, the unit conditions fall outside of the accident analysis assumptions.
Since automatic bank sequencing would continue to cause misalignment, the unit must be brought to a MODE or Condition in which the LCO requirements are not applicable.
To achieve this status, the unit must be brought to at least MODE 2 with K eff<1.0 within 6 hours.The allowed Completion Time is reasonable, based on operating experience, for reaching MODE 2 with K eff<1.0 from full power conditions in an orderly manner and without challenging plant systems.SURVEILLANCE REQUIREMENTS SR 3.1.4.1 that individual rod positions are within alignment limits at a Frequency of 12 hours provides a history that allows the operator to detect a rod that is beginning to deviate from its expected position.The specified Frequency takes into account other rod position information that is continuously available to the operator in the control room, so during actual rod motion, deviations can immediately be detected.'" l!:n.se n ,,?:;SR 3.1.4.2 Verifying each control rod is OPERABLE would require that each rod be tripped.However, in MODES 1 and 2 with Kef!1.0, tripping each control rod would result in radial or axial power tilts, or oscillations.
Exercising each individual control rod*rl92#'@provides increased confidence that all rods continue to be OPERABLE without exceeding the alignment limit, even if they are not regularly tripped.Moving each control roo by 10 steps will not cause radial or axial power tilts, or oscillations, to occur. 92 day Frequency takes into consideration other information WOGSTS B 3.1.4-8 Rev.3.0, 03/31/04 Rod Group Alignment Limits B 3.1.4 BASES -- SURVEILLANCE REQUIREMENTS (continued) available to the o~erator in the control room and SR 3.1.4.1. which is performed more irequentlygnd adds to the determination of OPERABILITY of the rods. Between required mformances of 6Seri 21 SR 3.1 "4.2 (determination of control rod OPERABILITY by moveient), if .F a control rod(s) is discovered to be immovable, but remains trippable, the control rod(s) is considered to be OPERABLE.
At any time, if a control rod(s) is immovable, a determination of the trippability (OPERABILITY) of the control rod(s) must be made, and appropriate action taken.
Verification of rod drop times allows the operator to determine that the maximum rod drop time permitted is consistent with the assumed rod drop time used in the safety analysis. Measuring rod drop times prior to reactor criticality, after reactor vessel head removal, ensures that the reactor internals and rod drive mechanism will not interfere with rod motion or rod drop time, and that no degradation in these systems has occurred that would adversely affect control rod motion or drop time. This testing is performed with all RCPs operating and the average moderator temperature 2 500&deg;F to simulate a reactor trip under actual conditions. This Surveillance is performed during a plant outage, due to the plant conditions needed to perform the SR and the potential for an unplanned plant transient if the Surveillance were performed with the reactor at power. - - - .- REFERENCES
: 1. I0 CFR 50, Appendix A, GDC 10 and GDC 26. 2. 10 CFR 50.46. 3. FSAR, Chapter 1151. 4. FSAR, Chapter [15]. 5. FSAR, Chapter
[15]. 6. FSAR, Chapter [15]. 7. FSAR, Chapter [15]. WOG STS Rev. 3.0, 03/31/04 Rod Group Alignment Limits B 3.1.4 BASES SURVEILLANCE REQUIREMENTS (continued) available to the operator in the control room and SR 3.1.4.1, which is performed more frequently qnd adds to the determination of 1""'"--"".
__OPERABILITY of the required performances 0 L\Ser Z SR 3.1.4.2 (determination of control rod OPERABILITY by movemen ,I a control rod(s)is discovered to be immovable, but remains trippable, the control rod(s)is considered to be OPERABLE.At any time, if a control rod(s)is immovable, a determination of the trippability (OPERABILITY) of the control rod(s)must be made, and appropriate action taken.SR 3.1.4.3 Verification of rod drop times allows the operator to determine that the maximum rod drop time permitted is consistent with the assumed rod drop time used in the safety analysis.Measuring rod drop times prior to reactor criticality, after reactor vessel head removal, ensures that the reactorinternalsand rod drive mechanism will not interfere with rod motion or rod drop time, and that no degradation in these systems has occurred that would adversely affect control rod motion or drop time.This testing is performed with all RCPs operating and the average moderator temperature;::
500&deg;F to simulate a reactor trip under actual conditions.
This Surveillance is performed during a plant outage, due to the plant conditions needed to perform the SR and the potential for an unplanned plant transient if the Surveillance were performed with the reactor at power.REFERENCES 1.10 CFR 50, Appendix A, GDC 10 and GDC 26.2.10 CFR 50.46.3.FSAR, Chapter[15].4.FSAR, Chapter[15].5.FSAR, Chapter[15].6.FSAR, Chapter[15].7.FSAR, Chapter[15].WOG STS B 3.1.4-9 Rev.3.0, 03/31/04 Shutdown Bank Insertion Limits
*3 3.1.5 BASES ACTIONS (continued) The allowed Completion Time of 2 hours provides an acceptable time for evaluating and repairing minor problems without allowing the plant to remain in an unacceptable condition for an extended period of time. If the shutdown banks cannot be restored to within their insertion limits within 2 hours, the unit must be brought to a MODE where the LC0 is not applicable. The allowed Completion Time of 6 hours is reasonable, based on operating experience, for reaching the required MODE from full power conditions in an orderly manner and without challenging plant systems. SURVEILLANCE SR 3.1.5.1 REQUIREMENTS Verification that the shutdown banks are within their insertion limits prior to an approach to criticality ensures that when the reactor is critical, or being taken critical, the shutdown banks will be available to shut down the reactor, and the required SDM will be maintained following a reactor trip.
This SR and Frequency ensure that the shutdown banks are withdrawn before the control banks are withdrawn during a unit startup. Ence the shutdown banks are positioned manually by the control room operator, a verification of shutdown bank position at a Frequency of 12 hours, after the reactor is taken critical, is adequate to ensure that they are within their insertion limits.
Also, the 12 hour Frequency takes into account other information available in the control room for the purpose of monitoring the status of shutdown rods. 6 ,"4*-n,8bTw,, REFERENCES
: 1. 10 CFR 50, Appendix A, GDC 10, GDC 26, and GDC 28. @%rtg -*a 2. 10 CFR 50.46. 3. FSAR, Chapter 1151. WOG Rev. 3.0, 03/31/04 Shutdown Bank Insertion Limits B 3.1.5 BASES ACTIONS (continued)
The allowed Completion Time of 2 hours provides an acceptable time for evaluating and repairing minor problems without allowing the plant to remain in an unacceptable condition for an extended period of time.If the shutdown banks cannot be restored to within their insertion limits within 2 hours, the unit must be brought to a MODE where the LCO is not applicable.
The allowed Completion Time of 6 hours is reasonable, based on operating experience,forreaching the required MODE from full power conditions in an orderly manner and without challenging plant systems.SURVEILLANCE REQUIREMENTS REFERENCES SR 3.1.5.1 Verification that the shutdown banks are within their insertion limits prior to an approach to criticalityensuresthat when the reactor is critical, or being taken critical, the shutdown banks will be available to shut down the reactor, and the required SDM will be maintained following a reactor trip.This SR and Frequency ensure that the shutdown banks are withdrawn before the control banks are withdrawn during a unit startup.&sect;nce the shutdown banks are positioned manually by the control room operator, a verification of shutdown bank position at a Frequency of 12 hours, after the reactor is taken critical, is adequate to ensure that they are within their insertion limits.Also, the 12 hour Frequency takes into account other information available in the control room for the purpose of monitoring the status of shutdown rods.t<=.....
1.10 CFR 50, Appendix A, GDC 10, GDC 26, and GDC 28.'-----, 2.10 CFR 50.46.3.FSAR, Chapter[15].WaG B 3.1.5-4 Rev.3.0, 03/31/04 Control Bank Insertion Limits B 3.1.6 BASES SURVEILLANCE SR 3.1 "6.1 REQUIREMENTS This Surveillance is required to ensure that the reactor does not achieve criticality with the control banks below their insertion limits. The estimated critical position (ECP) depends upon a number of factors, one of which is xenon concentration.
If the ECP was calculated long before criticality, xenon concentration could change to make the ECP substantially in error. Conversely, determining the ECP immediately before criticality could be an unnecessary burden. There are a number of unit parameters requiring operator attention at that point. Performing the ECP calculation within 4 hours prior to criticality avoids a large error from changes in xenon concentration, but allows the operator some flexibility to schedule the ECP calculation with other startup activities.
SR 3.1.6.2 Lrification of the control bank insertion limits at a Frequency of 12 hours is sufficient to detect control banks that may be approaching the insertion limits since, normally, very little rod motion occurs in 12 hours.
&ux> When control banks are maintained within their insertion limits as checked by SR 3.1.6.2 above, it is unlikely that their sequence and overlap will not be in accordance with requirements provided in the COLR. Frequency of 12 hours is consistent with the insertion limit check above in SR 3.1.6.2. .c*~-&.YL~rtfi
-- REFERENCES
: 1. 10 CFR 50, Appendix A, GDC 10, GDC 26, GDC 28. 2. 10 CFR 50.46. 3. FSAR, Chapter [I 51 4. FSAR, Chapter [15]. 5. FSAR, Chapter [15] WOG STS Rev. 3.0, 03/31/04 BASES SURVEILLANCE REQUIREMENTS REFERENCES Control Bank Insertion Limits B 3.1.6 SR 3.1.6.1 This Surveillance is required to ensure that the reactor does not achieve criticality with the control banks below their insertion limits.The estimated critical position (ECP)depends upon a number of factors, one of which is xenon concentration.
If the ECP was calculated long before criticality, xenon concentration could change to make the ECP substantially in error.Conversely, determining the ECP immediately before criticality could be an unnecessary burden.There are a number of unit parameters requiring operator attention at that point.Performing the ECP calculation within 4 hours priortocriticality avoids a large error from changes in xenon concentration, but allows the operator some flexibility to schedule the ECP calculation with other startup activities.
SR 3.1.6.2 Grification of the control bank insertion limits at a Frequency of 12 hours is sufficient to detect control banks that may be approaching the insertion limits since, normally, very little rod motion occurs in 12c0 er 9 SR 3.1.6.3 When control banks are maintained within their insertion limits as checked by SR 3.1.6.2 above, it is unlikely that their sequence and overlap will not be in accordance with requirements provided in the COLR.16 Frequency of 12 hours is consistent with the insertion limit check above in SR 3.1.6.2.'":=:1";r y,,;se;::::(U 1.10 CFR 50, Appendix A, GOC 10, GOC 26, GOC 28.2.10 CFR 50.46.3.FSAR, Chapter[15].4.FSAR, Chapter[15].5.FSAR, Chapter[15].WOGSTS B 3.1.6-5 Rev.3.0, 03/31/04 PHYSICS TESTS Exceptions - MODE 2 B 3.1.8 BASES ACTIONS (continued)
If the Required Actions cannot be completed within the associated Completion Time, the plant must be brought to a MODE in which the requirement does not apply. To achieve this status, the plant must be brought to at least MODE 3 within an additional 15 minutes. The Completion Time of 15 additional minutes is reasonable, based on operating experience, for reaching MODE 3 in an orderly manner and without challenging plant systems.
SURVEILLANCE SR 3.1.8.1 REQUIREMENTS The power range and intermediate range neutron detectors must be verified to be OPERABLE in MODE 2 by LC0 3.3.1, "Reactor Trip System (RTS) Instrumentation." A CHANNEL OPERATIONAL TEST is performed on each power range and intermediate range channel prior to initiation of the PHYSICS TESTS. This will ensure that the RTS is properly aligned to provide the required degree of core protection during the performance of the PHYSICS TESTS.
Verification that the RCS lowest loop T,,, is 2 531 "F will ensure that the unit is not o erating in a condition that could invalidate the safety analyses.$erification of the RCS temperature at a Frequency of 30 minutes during the performance of the PHYSICS TESTS will ensure that the initial conditions of the safety analyses are not violated.
CI*) Verification that the THERMAL POWER is
< 5% RTP will ensure that the plant is not operating in a condition that could invalidate the safety analyses.Eerification of the THERMAL POWER at a Frequency of 30 minutes during the performance of the PHYSICS TESTS will ensure that the initial conditions of the safety analyses are not viola &*Q WOG STS B 3.1.8-7 Rev. 3.0, 03/31/04 PHYSICS TESTS Exceptions
-MODE 2 B 3.1.8 BASES ACTIONS (continued)
If the Required Actions cannot be completed within the associated Completion Time, the plant must be brought to a MODE in which the requirement does not apply.To achieve this status, the plant must be brought to at least MODE 3 within an additional 15 minutes.The Completion Time of 15 additional minutes is reasonable, based on operating experience, for reaching MODE 3 in an orderly manner and without challenging plant systems.SURVEILLANCE REQUIREMENTS SR 3.1.8.1 The power range and intermediate range neutron detectors must be verified to be OPERABLE in MODE 2 by LCO 3.3.1,"Reactor Trip System (RTS)Instrumentation." A CHANNEL OPERATIONAL TEST is performed on each power range and intermediate range channel prior to initiation of the PHYSICS TESTS.This will ensure that the RTS is properly aligned to provide the required degree of core protection during the performance of the PHYSICS TESTS.SR 3.1.8.2 Verification that the RCS lowest loop T avg is531&deg;F will ensure that the unit is notf.U?erating in a condition that could invalidate the safety analyses.C{erification of the RCS temperature at a Frequency of 30 minutes during the performance of the PHYSICS TESTS will ensure that the initial conditions of the safety analyses are not
.....
:r:nSe r SR 3.1.8.3 Verification that the THERMAL POWER is$5%RTP will ensure that the plant is not operating in a condition that could invalidate the safety analyses.[yerification of the THERMAL POWER at a Frequency of 30 minutes during the performance of the PHYSICS TESTS will ensure that the initial conditions of the safety analyses are not InSer-...WOGSTS B 3.1.8-7 Rev.3.0, 03/31/04 PHYSICS TESTS Exceptions - MODE 2 B 3.1.8 BASES SURVEILLANCE REQUIREMENTS (continued) The SDM is verified by performing a reactivity balance calculation, considering the following reactivity effects: a. RCS boron concentration. b. Control bank position, c. RCS average temperature, d. Fuel burnup based on gross thermal energy generation, e. Xenon concentration, f. Samarium concentration, g. Isothermal temperature coefficient (ITC), when below the point of adding heat (POAH), h. Moderate defect, when above the POAH, and i. Doppler defect, when above the POAH. Using the ITC accounts for Doppler reactivity in this calculation when the reactor is subcritical or critical but below the POAH, and the fuel temperature will be changing at the same rate as the RCS. Ee Frequency of 24 hours is based on the generally slow change in required boron concentration and on the low probabilitp of an accident occurring without the required SDM. & REFERENCES
: 1. 10 CFR 50, Appendix B, Section XI. lG n5c rt 2. 10 CFR 50.59. 3. Regulatory Guide 1.68, Revision 2, August, 1978. 4. ANSIIANS-19.6.1-1985, December 13, 1985. 5. WCAP-9273-NP-A, "Westinghouse Reload Safety Evaluation Methodology Report," July 1985. 6. WCAP-1 I61 8, including Addendum 1, April 1989. WOG STS B 3.1.8-8 Rev. 3.0, 03/31/04 PHYSICS TESTS Exceptions w MODE 2 B 3.1.8 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.1.8.4 The SDM is verified by performing a reactivity balance calculation, considering the following reactivity effects: a.RCS boron concentration, b.Control bank position, c.RCS average temperature, d.Fuel burnup based on gross thermalenergygeneration, e.Xenon concentration, f.Samarium concentration, g.Isothermal temperature coefficient (lTC), when below the point of adding heat (POAH), h.Moderate defect, when above the POAH, and i.Doppler defect, when above the POAH.Using the ITC accounts for Doppler reactivity in this calculation when the reactor is subcritical or critical but below the POAH, and the fuel temperature will be changing at the same rate as the RCS.fihe Frequency of 24 hours is based on the generally slow change in required boron concentration and on the low probability of an accident occurring without the required SDM.REFERENCES 1.10 CFR 50, Appendix B, Section XI.2.10 CFR 50.59.3.Regulatory Guide 1.68, Revision 2, August, 1978.4.ANSI/ANS-19.6.1-1985, December 13,1985.5.WCAP-9273-NP-A,"Westinghouse Reload Safety Evaluation Methodology Report," July 1985.6.WCAP-11618, including Addendum 1, April 1989.WOGSTS B 3.1.8-8 Rev.3.0, 03/31/04 Fa(Z) (CAOC-F,, Methodology)
B 3.2.1A BASES -- SURVEILLANCE REQUIREMENTS (continued)
Ee Frequency of 31 EFPD is adequate for monitoring the change of power distribution with core burnup because the power distribution changes relatively slowly for this amount of fuel burnup. The Surveillance may be done more frequently if required by the results of SR SR 3.2.1.2 The nuclear design process includes calculations performed to determine that the core can be operated within the FQ(Z) limits. Because flux maps are taken at steady state conditions, the axial variations in power distribution for normal operation maneuvers such as load following are not present in the flux map data. These axial variations are, however, conservatively calculated by considering, in the nuclear design process, a wide range of unit maneuvers in normal operation.
F,(Z) is the radial peaking factor, which is one component of FQ(Z) and should be consistent between the nuclear design values and the measured values. (F,,(Z) multiplied by the normalized average axial power at elevation Z gives FCdZ).) The core plane regions applicable to an Fxy evaluation exclude the following, measured in percent of core height:
: a. Lower core region, from 0% to 15% inclusive, b. Upper core region, from 85% to 100% inclusive, c. Grid plane regions, f 2% inclusive, and
: d. Core plane regions, within
+ 2% of the bank demand position of the control banks.
The following terms are used in the Fxy evaluation:
Fk = The measured value of FxY obtained directly from the flux map results.
Fk = The measured value, F,M,, multiplied by 1.0815 to account for fuel manufacturing tolerances and flux map measurement uncertainty (Ref. 2). WOG STS B 3.2.1A-6 Rev. 3.0, 03/31/04 Fa(Z)(CAOC-F xy Methodology)
B 3.2.1A BASES SURVEILLANCE REQUIREMENTS (continued) ille Frequency of 31 EFPD is adequate for monitoring the change of power distribution with core burnup because the power distribution changes relatively slowly for this amount of fuel burnup.The Surveillance may be done more frequently if required by the results of SR 3.2.
SR 3.2.1.2 The nuclear design process includes calculations performed to determine that the core can be operated within the Fo(Z)limits.Because flux maps are taken at steady state conditions, the axial variations in power distribution for normal operation maneuvers such as load following are not present in the flux map data.These axial variations are, however, conservatively calculated by considering, in the nuclear design process, a wide range of unit maneuvers in normal operation.
Fxy(Z)is the radial peaking factor, which is one component of Fa(Z)and should be consistent between the nuclear design values and the measured values.(Fxy(Z)multiplied by the normalized average axial power at elevation Z gives Fo(Z).)The core plane regions applicable to an F xy evaluation exclude the following, measured in percent of core height: a.Lower core region, from 0%to 15%inclusive, b.Upper core region, from 85%to 100%inclusive, c.Grid plane regions,+/-2%inclusive, and d.Core plane regions, within+/-2%of the bank demand position of the control banks.The following terms are used in the F xy evaluation:=The measured value of F xy obtained directly from the flux map results.F;y=The measured value, multiplied by 1.0815 to account for fuel manufacturing tolerances and flux map measurement uncertainty (Ref.2).WOGSTS B 3.2.1A-6 Rev.3.0, 03/31/04 FQ(Z) (CAOC-F,, Methodology)
B 3.2.1A BASES SURVEILLANCE REQUIREMENTS (continued) The first Note of this Surveillance provides the action to be taken if FS is > F,R,TP In this case, the FQ(Z) limit may be exceeded. Proportionally increasing the predicted F,PR(Z) by the amount that FA is exceeded gives an adjusted F,(Z), which is compared with the FQ(Z) limit. If the adjusted FQ(Z) exceeds the LC0 limit, the operator must perform Required Actions A.l through AS. The second Note in this Surveillance states that if fk is > F,R,TP but c Fky then this Surveillance shall be repeated within 24 hours after exceeding by r 20% RTP the THERMAL POWER at which F& was last determined, so as to demonstrate that F,,(Z) is being sufficiently reduced as power increases. This reduction, because of feedback from the Doppler coefficient and moderator effects, ensures that when RTP is attained, the computed F,C, (Z) is < F,R,TP . Performing the Surveillance in MODE I prior to exceeding 75% RTP after each refueling ensures that the Fa(Z) limit is met when RTP is achieved.
@e Surveillance Frequency of 31 EFPD is adequate to monitor the change of power distribution with core burnup because the power distribution changes relatively slowly for this amount of fuel burnup. The Surveillance may be done more frequently if required by the results of F,, evaluations. Specifically, the F,, evaluation is required by this Surveillance if the evaluation shows that FgP < F& and to demonstrate that the LC0 is met after its limit has been exceeded.
h REFERENCES
: 1. 10 CFR 50.46. 2. Regulatory Guide 1.77, Rev. [ 1. 3. 10 CFR 50.46, GDC 26. [ 4. WCAP-7308-L-P-A, "Evaluation of Nuclear Hot Channel Factor Uncertainties," June 1988. 1 WOG STS Rev. 3.0, 03/31/04 Fo{Z)(CAOC-F xy Methodology)
B 3.2.1A BASES SURVEILLANCE REQUIREMENTS (continued)
The first Note of this Surveillance provides the action to be taken if F;y is> In this case, the Fo{Z)limit may be exceeded.Proportionally increasing the predicted F<';R (Z)by the amount that;s exceeded gives an adjusted Fa(Z), which is compared with the Fo{Z)limit.If the adjusted Fo{Z)exceeds the LCO limit, the operator must perform Required Actions A.1 through A.5.The second Note in this Surveillance states that if F;y is>FfJP but< then this Surveillance shall be repeated within 24hoursafter exceeding by 2: 20%RTP the THERMAL POWER at which F;y was last determined, so as to demonstrate that Fxy(Z)is being sufficiently reduced as power increases.
This reduction, because of feedback from the Doppler coefficient and moderator effects, ensures that when RTP is attained, the computed F;y (Z)is<FfY.REFERENCES Performing the Surveillance in MODE 1 prior to exceeding 75%RTP after each refueling ensures that the Fo{Z)limit is met when RTP is achieved.m;e Surveillance Frequency of 31 EFPD is adequate to monitor the change of power distribution with core burnup because the power distribution changes relatively slowly for this amount of fuel burnup.The Surveillance may be done more frequently if required by the results of F xy evaluations.
Specifically, the F xy evaluation is required by this Surveillance if the evaluation shows that FNP<F;y and to demonstrate that the LCO is met after its limit has been exceeded.1.10 CFR 50.46.2.Regulatory Guide 1.77, Rev.[].3.10 CFR 50.46, GOC 26.[4.WCAP-7308-L-P-A,"Evaluation of Nuclear Hot Channel Factor Uncertainties," June 1988.]WOG STS B 3.2.1A-8 Rev.3.0, 03/31/04 FQ(Z) (RAOC-W(Z)
Methodology)
B 3.2.16 BASES SURVEILLANCE REQUIREMENTS (continued) increase power to RTP and operate for 31 days without verification of F,C(Z) and F,W (Z) . The Frequency condition is not intended to require verification of these parameters after every 10% increase in power level above the last verification. It only requires verification after a power level is achieved for extended operation that is 10% higher than that power at which Fa(Z) was last measured. Verification that F,C(Z) is within its specified limits involves increasing F&f(Z) to allow for manufacturing tolerance and measurement uncertainties in order to obtain F,C(Z). Specifically, F,M(Z) is the measured value of Fa(Z) obtained from incore flux map results and F,C(Z) = F,M(Z) [1.0815] (Ref. 4). F,C(Z) is then compared to its specified limits. The limit with which F,C(Z) is compared varies inversely with power above 50% RTP and directly with a function called K(Z) provided in the COLR. Performing this Surveillance in MODE 1 prior to exceeding 75%
RTP ensures that the F;(Z) limit is met when RTP is achieved, because peaking factors generally decrease as power level is increased. If THERMAL POWER has been increased by 2 10% RTP since the last determination of F,C(Z), another evaluation of this factor is required
[I21 hours after achieving equilibrium conditions at this higher power level (to ensure that F,C(Z) values are being reduced sufficiently with power increase to stay within the LC0 limits). Ehhe Frequency of 31 EFPD is adequate to monitor the change of power distribution with core burnup because such changes are slow and well controlled when the plant is operated in accordance with the Technical Specifications (TS).
+-_/."*"I ,T- c<i < ;*""rn .-.---* WOG STS - Rev. 3.0, 03/31/04 Fo(Z)(RAOC-W(Z)
Methodology)
B 3.2.1B BASES SURVEILLANCE REQUIREMENTS (continued) increase power to RTP and operate for 31 days without verification of Fg (Z)and F6" (Z).The Frequency condition is not intended to require verification of these parameters after every 10%increase in power level above the last verification.
It only requires verification after a power level is achieved for extended operation that is 10%higher than that power at which Fa{Z)was last measured.SR 3.2.1.1 Verification that Fg (Z)is within its specified limits involves increasing(Z)to allow for manufacturing tolerance and measurement uncertainties in order to obtain Fg(Z).Specifically,
;s the measured value of Fa{Z)obtained from incore flux map results and Fg(Z)=
[1.0815](Ref.4).Fg(Z)is then compared to its specified limits.The limit with which Fg (Z)is compared varies inversely with power above 50%RTP and directly with a function called K{Z)provided in the COLR.Performing this Surveillance in MODE 1 prior to exceeding 75%RTP ensures that the F8(Z)limit is met when RTP is achieved, because peaking factors generally decrease as power level is increased.
If THERMAL POWER has been increased by10%RTP since the last determination of F8(Z), another evaluation of this factor is required[12J hours after achieving equilibrium conditions at this higher power level (to ensure that Fg(Z)values are being reduced sufficiently with power increase to stay within the LCO limits).C!De Frequency of 31 EFPD is adequate to monitor the change of power distribution with core burnup because such changes are slow and well controlled when the plant is operated in accordance with the Technical Specifications (TS).
.-1_n-',_J".[-::-;.)
WOGSTS B 3.2.18-8 Rev.3.0, 03/31104 BASES SURVEILLANCE REQUl REMENTS (continued)
---------h-----d--------h-----m----
R EVI EWER'S NOTE------------
------------------ - ---- WCAP-10216-P-A, Rev. IA, "Relaxation of Constant Axial Offset Control and Fa Surveillance Technical Specification," February 1994, or other appropriate plant specific methodology, is to be listed in the COLR description in the Administrative Controls Section 5.0 to address the methodology used to derive this factor. ------------------------------------------m--*"---"m*------m-----m*---------------"------"-------- or to evaluate FQ(Z) more frequently, each 7 EFPD. These alternative requirements prevent FQ(Z) from exceeding its limit for any significant period of time without detection. Performing the Surveillance in MODE I prior to exceeding 75% RTP ensures that the FQ(Z) limit is met when RTP is achieved, because peaking factors are generally decreased as power level is increased.
FQ(Z) is verified at power levels 2 10% RTP above the THERMAL POWER of its last verification, [I21 hours after achieving equilibrium conditions to ensure that FQ(Z) is within its limit at higher power levels.
Ehe Surveillance Frequency of 31 EFPD is adequate to monitor the change of power distribution with core burnup. The Surveillance may be done more frequently if required by the results of Fa(Z) evaluations. The Frequency of 31 EFPD is adequate to monitor the change of power distribution because such a change is sufficiently slow, when the plant is operated in accordance with the TS, to preclude adverse peaking factors between 31 day surveillances.
REFERENCES I I0 CFR 50.46, 1974.
u 2. Regulatory Guide 1.77, Rev.
0, May 1974. 3. 10 CFR 50, Appendix A, GDC 26. 4. WCAP-7308-L-P-A, "Evaluation of Nuclear Hot Channel Factor Uncertainties," June 1988. 5. WCAP-10216-P-A, Rev. 1 A, "Relaxation of Constant Axial Offset Control (and) FQ Surveillance Technical Specification," February 1994. WOE STS Rev. 3.0, 03/31/04 Fa(Z)(RAOC-W(Z)
Methodology) 83.2.18 8ASES SURVEILLANCE REQUIREMENTS (continued)
-----------------------------------RE\lIEWER'S NOTE-----------------------------------
WCAP-10216-P-A, Rev.1A,"Relaxation of Constant Axial Offset Control and Fa Surveillance Technical Specification," February 1994, or other appropriate plant specific methodology, is to be listed in the COLR description in the Administrative Controls Section 5.0 to address the methodology used to derive this factor.or to evaluate Fa(Z)more frequently, each 7 EFPD.These alternative requirements prevent Fo(Z)from exceeding its limit for any significant period of time without detection.
Performing the Surveillance in MODE 1 prior to exceeding 75%RTP ensures that the Fa(Z)limit is met when RTP is achieved, because peaking factors are generally decreased as power level is increased.
Fa(Z)is verified at power levels 2: 10%RTP above the THERMAL POWER of its last verification,[12]hours after achieving equilibrium conditions to ensure that Fo(Z)is within its limit at higher power levels.[The Surveillance Frequency of 31 EFPO is adequate to monitor the change of power distribution with core burnup.The Surveillance may be done more frequently if required by the results of Fo(Z)evaluations.
The Frequency of 31 EFPD is adequate to monitor the change of power distribution because such a change is sufficiently slow, when the plant is operated in accordance with the TS, to preclude adverse peaking factors between 31 day
___REFERENCES 1.10 CFR 50.46, 1974.2.Regulatory Guide 1.77, Rev.0, May 1974.3.10 CFR 50, Appendix A, GOC 26.4.WCAP-7308-L-P-A,"Evaluation of Nuclear Hot Channel Factor Uncertainties," June 1988.5.WCAP-10216-P-A, Rev.1A,"Relaxation of Constant Axial Offset Control (and)Fa Surveillance Technical Specification," February 1994.WOGSTS 83.2.18-10 Rev.3.0, 03/31/04 FQ(Z) (CAOC-W(Z)
Methodology)
B 3.2.1C BASES SURVEILLANCE REQUIREMENTS (continued)
Verification that F,C(Z) is within its specified limits involves increasing F,M(Z) to allow for manufacturing tolerance and measurement uncertainties in order to obtain F,C(Z). Specifically, F,M(Z) is the measured value of FQ(Z) obtained from incore flux map results and F,C(Z) = F,M(Z) [I .0815] (Ref. 4).
Fg(Z) is then compared to its specified limits. The limit with which F,C(Z) is compared varies inversely with power above 50% RTP and directly with a function called K(Z) provided in the COLR. Performing this Surveillance in MODE 1 prior to exceeding 75% RTP ensures that the F,C(Z) limit is met when RTP is achieved, because peaking factors generally decrease as power level is increased. If THERMAL POWER has been increased by 2 10% RTP since the last determination of F,C(Z), another evaluation of this factor is required
[I21 hours after achieving equilibrium conditions at this higher power level (to ensure that F,C(Z) values are being reduced sufficiently with power increase to stay within the LC0 limits). Ee Frequency of 31 EFPD is adequate to monitor the change of power distribution with core burnup because such changes are slow and well controlled when the plant is operated in accordance with the Technical Specifications (TS).
+ The nuclear design process includes calculations performed to determine that the core can be operated within the Fo(Z) limits. Because flux maps are taken in steady state conditions, the variations in power distribution resulting from normal operational maneuvers are not present in the flux map data. These variations are, however, conservatively calculated by considering a wide range of unit maneuvers in normal operation.
The maximum peaking factor increase over steady state values, calculated as a function of core elevation, Z, is called W(Z). Multiplying the measured total peaking factor, F;(Z), by W(Z) gives the maximum Fa(Z) calculated to occur in normal operation, F,W (Z) . WOG STS B 3.2.1C-8 Rev. 3.0, 03/31/04 FQ(Z)(CAOC-W(Z)
Methodology)
B 3.2.1C BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.2.1.1 Verification that Fg(Z)is within its specified limits involves increasing to allow for manufacturing tolerance and measurement uncertainties in order to obtain Fg(Z).Specifically, is the measured value of FQ(Z)obtained from incore flux map results and Fg(Z)=
[1.0815](Ref.4).Fg(Z)is then compared to its specified limits.The limit with which Fg(Z)is compared varies inversely with power above 50%RTP and directly with a function called K(Z)prQvided in the COLR.Performing this Surveillance in MODE 1 prior to exceeding 75%RTP ensures that the Fg(Z)limit is met when RTP is achieved, because peaking factors generally decrease as power level is increased.
If THERMAL POWER has been increased by<:: 10%RTP since the last determination of Fg (Z), another evaluation of this factor is required[12]hours after achieving equilibrium conditions at this higher power level (to ensure that Fg(Z)values are being reduced sufficiently with power increase to stay within the LCO limits).[I;e Frequency of 31 EFPD is adequate to monitor the change of power distribution with core burnup because such changes are slow and well controlled when the plant is operated in accordance with the Technical Specifications (TS).
SR 3.2.1.2 The nuclear design process includes calculations performed to determine that the core can be operated within the Fo(Z)limits.Because flux maps are taken in steady state conditions, the variations in power distribution resulting from normal operational maneuvers are not present in the flux map data.These variations are, however, conservatively calculated by considering a wide range of unit maneuvers in normal operation.
The maximum peaking factor increase over steady state values, calculated as a function of core elevation, Z, is called W(Z).Multiplying the measured total peaking factor, Fci(Z), by W(Z)gives the maximum Fo(Z)calculated to occur in normal operation,(Z).-WOGSTS B 3.2.1C-8 Rev.3.0.03/31/04 Fo(Z) (CAOC-W(Z)
Methodology)
B 3.2.1C BASES SURVEILLANCE REQUIREMENTS (continued)
Performing the Surveillance in MODE 1 prior to exceeding 75% RTP ensures that the FQ(Z) limit is met when RTP is achieved, because peaking factors are generally decreased as power level is increased.
FQ(Z) is verified at power levels r 10% RTP above the THERMAL POWER of its last verification, [I21 hours after achieving equilibrium conditions to ensure that FQ(Z) is within its limit at higher power levels.
The Surveillance Frequency of 31 EFPD is adequate to monitor the c ange of power distribution with core burnup. The Surveillance may be G done more frequently if required by the results of F&) evaluations. The Frequency of 31 EFPD is adequate to monitor the change of power distribution because such a change is sufficiently slow, when the plant is
-- REFERENCES
: 1. 10 CFR 50.46, 1974. 2. Regulatory Guide 1.77, Rev. 0, May 1974.
: 3. 10 CFR 50, Appendix A, GDC 26. 4. WCAP-7308-L-P-A, "Evaluation of Nuclear Hot Channel Factor Uncertainties," June 1988.
: 5. WCAP-10216-P-A, Rev. 1 A, "Relaxation of Constant Axial Offset Control (and)
FQ Surveillance Technical Specification," February 1994.
WOG STS Rev. 3.0, 03/31/04 Fo(Z)(CAOC-W(Z)
Methodology)
B 3.2.1C BASES SURVEILLANCE REQUIREMENTS (continued)
Performing the Surveillance in MODE 1 prior to exceeding 75%RTP ensures that the Fa(Z)limit is met when RTP is achieved, because peaking factors are generally decreased as power level is increased.
Fa(Z)is verified at power levels10%RTP above the THERMAL POWER of its last verification,[12]hours after achieving equilibrium conditions to ensure that Fo(Z)is within its limit at higher power levels.lThe Surveillance Frequency of 31 EFPD is adequate to monitor the'a;ange of power distribution with core burnup.The Surveillance may be done more frequently if required by the results of Fa(Z)evaluations.
The Frequency of 31 EFPD is adequate to monitor the change of power distribution because such a change is sufficiently slow,whenthe plant is operated in accordance with the TS, to preclude a erse eaki factors between 31 day surveillances....,.., r,C er""" r REFERENCES 1.10 CFR 50.46,1974.
2.Regulatory Guide 1.77, Rev.0, May 1974.3.10 CFR 50, Appendix A, GDC 26.4.WCAP-7308-L-P-A,"Evaluation of Nuclear Hot Channel Factor Uncertainties," June 1988.5.WCAP-10216-P-A, Rev.1A,"Relaxation of Constant Axial Offset Control (and)Fa Surveillance Technical Specification," February 1994.WOGSTS B 3.2.1C-10 Rev.3.0, 03/31/04 BASES ACTIONS (continued)
Verification that FtH is within its specified limits after an out of limit occurrence ensures that the cause that led to the F! exceeding its limit is corrected, and that subsequent operation proceeds within the LC0 limit. This Action demonstrates that the F: limit is within the LC0 limits prior to exceeding 50% RTP, again prior to exceeding 75% RTP, and within 24 hours after THERMAL POWER is r 95% RTP. This Required Action is modified by a Note that states that THERMAL POWER does not have to be reduced prior to performing this Action. When Required Actions A.l.l through A.3 cannot be completed within their required Completion Times, the plant must be placed in a mode in which the LC0 requirements are not applicable.
This is done by placing the plant in at least MODE 2 within 6 hours. The allowed Completion Time of 6 hours is reasonable, based on operating experience regarding the time required to reach MODE 2 from full power conditions in an orderly manner and without challenging plant systems.
SURVEILLANCE SR 3.2.2.1 REQUIREMENTS The value of F!. is determined by using the movable incore detector system to obtain a flux distribution map.
A data reduction computer program then calculates the maximum value of F: from the measured flux distributions.
The measured value of F! must be multiplied by 1.04 to account for measurement uncertainty before making comparisons to the F: ,, limit. After each refueling, must be determined in MODE 1 prior to exceeding 75% RTP. This requirement ensures that F:~ limits are met at the beginning of each fuel cycle. Ehe 31 EFPD Frequency is acceptable because the power distribution changes relatively slowly over this amount of fuel burnup. Accordingly, this Frequency is short enough that the F! limit cannot be exceeded for any significant period of operation.
C~~se;m WOG STS B 3.2.2-6 Revision No.
2.2  B 3.2.2 BASES ACTIONS (continued)
Verification thatH is within its specified limits after an out of limit occurrence ensures that the cause that led to theH exceeding its limit is corrected, and that subsequent operation proceeds within the LCO limit.This Action demonstrates that theH limit is within the LCO limits prior to exceeding 50%RTP, again prior to exceeding 75%RTP, and within 24hoursafter THERMAL POWER is95%RTP.This Required Action is modified by a Note that states that THERMAL POWER does not have to be reduced prior to performing this Action.When Required Actions A.1.1 through A.3 cannot be completed within their required Completion Times, the plant must be placed in a mode in which the LCO requirements are not applicable.
This is done by placing the plant in at least MODE 2 within 6 hours.The allowed Completion Time of 6 hours is reasonable, based on operating experience regarding the time required to reach MODE 2 from full power conditions in an orderly manner and without challenging plant systems.SURVEILLANCE REQUIREMENTS SR 3.2.2.1 The value ofH is determined by using the movable incore detector system to obtain a flux distribution map.A data reduction computer program then calculates the maximum value ofH from the measured flux distributions.
The measured value ofH must be multiplied by 1.04 to account for measurement uncertainty before making comparisons to theH limit.After each refueling,H must be determined in MODE 1 prior to exceeding 75%RTP.This requirement ensures thatH limits are met at the beginning of each fuel cycle.[lhe 31 EFPD Frequency is acceptable because the power distribution changes relatively slowly over this amount of fuel burnup.Accordingly, this Frequency is short enough that theH limit cannot be exceeded for any significant period of operation.
<
1)WOG STS B 3.2.2-6 Revision No.2.2 AFD (CAOC Methodology)
B 3.2.3A BASES ACTIONS (continued)
If Required Action C.1 is not completed within its required Completion Time of 30 minutes, the axial xenon distribution starts to become significantly skewed with the THERMAL POWER 2 50% RTP. In this situation, the assumption that a cumulative penalty deviation time of 1 hour or less during the previous 24 hours while the AFD is outside its target band is acceptable at c 50% RTP, is no longer valid. Reducing the power level to < 15% RTP within the Completion Time of 9 hours and complying with LC0 penalty deviation time requirements for subsequent increases in THERMAL POWER ensure that acceptable xenon conditions are restored. This Required Action must also be implemented either if the cumulative penalty deviation time is > I hour during the previous 24 hours, or the AFD is not within the target band and not within the acceptable operation limits. SURVEILLANCE SR 3.2.3.1 REQUIREMENTS This Surveillance verifies that the AFD as indicated by the NIS excore channels is within the target band.
@e Surveillance Frequency of 7 days is adequate because the AFD is controlled by the operator and monitored by the process computer.
Furthermore, any deviations of the AFD from the target band that is not alarmed should be readily noticed.
+-ffF&Za The AFD should be monitored and logged more frequently in periods of operation for which the power level or control bank positions are changing to allow corrective measures when the AFD is more likely to move outside the target band.
chis Surveillance requires that the target flux difference is updated at a Frequency of 31 effective full power days (EFPD) to account for small changes that may occur in the target flux differences in that period due to burnup by performing SR 3.2.3.3.c - nsc~2) Alternatively, linear interpolation between the most recent measurement of the target flux differences and a predicted end of cycle value provides a reasonable update because the AFD changes due to burnup tend toward 0% AFD. When the predicted end of cycle AFD from the cycle nuclear design is different from 0%, it may be a better value for the interpolation.
WOG STS B 3.2.3A-6 Rev. 3.0, 03/31/04 AFD (CAOC Methodology)
B 3.2.3A BASES ACTIONS (continued)
If Required Action C.1 is not completed within its required Completion Time of 30 minutes, the axial xenon distribution starts to become significantly skewed with the THERMAL POWER50%RTP.In this situation, the assumption that a cumulative penalty deviation time of 1 hour or less during the previous 24 hours while the AFD is outside its target band is acceptable at<50%RTP.is no longer valid.Reducing the power level to<15%RTP within the Completion Time of 9 hours and complying with LCO penalty deviation time requirements for subsequent increases in THERMAL POWER ensure that acceptable xenon conditions are restored.This Required Action must also be implemented either if the cumulative penalty deviation time is>1 hour during the previous 24 hours, or the AFD is not within the target band and not within the acceptable operation limits.SURVEILLANCE REQUIREMENTS SR 3.2.3.1 This Surveillance verifies that the AFD as indicated by the NIS excore channels is within the target band.I!he Surveillance Frequency of 7 days is adequate because the AFD is controlled by the operator and monitored by the process computer.Furthermore.
any deviations of the AFD from@.the target band that is not alarmed should be readily Z The AFD should be monitored and logged more frequently in periods of operation for which the power level or control bank positions are changing to allow corrective measures when the AFD is more likely to move outside the target band.SR 3.2.3.2[This Surveillance requires that the target flux difference is updated at a Frequency of 31 effective full power days (EFPO)to account for small changes that may occur in the target flux differences in that period due to burnup by performing SR 3.2.3.3.
(;i noS])Alternatively, linear interpolation between the most recent measurement of the target flux differences and a predicted end of cycle value provides a reasonable update because the AFD changes due to burnup tend toward 0%AFD.When the predicted end of cycle AFD from the cycle nuclear design is different from 0%, it may be a better value for the interpolation.
WOGSTS B 3.2.3A-6 Rev.3.0.03/31/04 AFD (CAOC Methodology)
B 3.2.3A BASES SURVEILLANCE REQUIREMENTS (continued) Measurement of the target flux difference is accomplished by taking a flux map when the core is at equilibrium xenon conditions, preferably at high power levels with the control banks nearly withdrawn. This flux map provides the equilibrium xenon axial power distribution from which the target value can be determined.
The target flux difference varies slowly with core burnup. G~requency of 31 EFPD after each refueling and 92 EFPD thereafter for remeasuring the target flux differences adjusts the target flux difference for each excore channel to the value measured at This is the basis for the CAOC. Remeasurement interval also establishes the AFD target flux difference values that account for changes in incore excore calibrations in the interim.&------
-------"...-
A Note modifies this SR to allow the predicted end of cycle AFD from the cycle nuclear design to be used to determine the initial target flux difference after each refueling.
REFERENCES
: 1. WCAP-8403 (nonproprietary), "Power Distribution Control and Load Following Procedures," Westinghouse Electric Corporation, September 1974. 2. T. M. Anderson to K. Kniel (Chief of Core Performance Branch, NRC),
 
==Attachment:==
"Operation and Safety Analysis Aspects of an Improved Load Follow Package," January 31, 1980. 3. C. Eicheldinger to D. B. Vassallo (Chief of Light Water Reactors Branch, NRC), Letter NS-CE-687, July 16, 1975. 4. FSAR, Chapter [15]. WOG STS Rev. 3.0, 03/31/04 AFD (CAOC Methodology)
B 3.2.3A BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.2.3.3 Measurement of the target flux difference is accomplished by taking a flux mapwhenthe core is at equilibrium xenon conditions, preferably at high power levels with the control banks nearly withdrawn.
This flux map provides the equilibrium xenon axial power distribution from which the target value can be determined.
The target flux difference varies slowly with core burnup.Frequency of 31 EFPD after each refueling and 92 EFPD thereafter for remeasuring the target flux differences adjusts the target flux difference for each excore channel to the value measured at steady state
__--t_This is the basis for the CAOC.Remeasurement at this Surveillance
:lnSe.r interval also establishes the AFD target flux difference values that account for changes in incore excore calibrations that may have occurred in the
-----------------
A Note modifies this SR to allow the predicted end of cycle AFD from the cycle nuclear design to beusedto determine the initial target flux difference after each refueling.
REFERENCES 1.WCAP-8403 (nonproprietary),"Power Distribution Control and Load Following Procedures," Westinghouse Electric Corporation, September 1974.2.T.M.Anderson to K.Kniel (Chief of Core Performance Branch, NRC),
 
==Attachment:==
"Operation and Safety Analysis Aspects of an Improved Load Follow Package," January 31,1980.3.C.Eicheldinger to D.B.Vassallo (Chief of Light Water Reactors Branch, NRC), Letter NS-CE-687, July 16, 1975.4.FSAR, Chapter[15].WOGSTS B 3.2.3A-7 Rev.3.0, 03/31/04 AFD (RAOC Methodology)
B 3.2.3B BASES LC0 (continued)
The AFD limits are provided in the COLR. Figure B 3.2.36-1 shows typical RAOC AFD limits. The AFD limits for RAOC do not depend on the target flux difference.
However, the target flux difference may be used to minimize changes in the axial power distribution. Violating this LC0 on the AFD could produce unacceptable consequences if a Condition 2,3, or 4 event occurs while the AFD is outside its specified limits.
APPLICABILITY The AFD requirements are applicable in MODE 1 greater than or equal to 50% RTP when the combination of THERMAL POWER and core peaking factors are of primary importance in safety analysis.
For AFD limits developed using RAOC methodology, the value of the AFD does not affect the limiting accident consequences with THERMAL POWER < 50% RTP and for lower operating power MODES.
ACTIONS As an alternative to restoring the AFD to within its specified limits, Required Action A.l requires a THERMAL POWER reduction to
< 50% RTP. This places the core in a condition for which the value of the AFD is not important in the applicable safety analyses. A Completion Time of 30 minutes is reasonable, based on operating experience, to reach 50% RTP without challenging plant systems. SURVEILLANCE SR 3.2.3.1 REQUIREMENTS This Surveillance verifies that the AFD as indicated by the NIS excore channel, is within its specified limits.
Ehe Surveillance Frequency of 7 days is adequate considering that the AFD is monitored by a computer and any deviation from requirements is alarmed.
4 fbsevm REFERENCES I WCAP-8403 (nonproprietary), "Power Distribution Control and Load Following Procedures," Westinghouse Electric Corporation, September 1974.
: 2. R. W. Miller et al., "Relaxation of Constant Axial Offset Control:
FQ Surveillance Technical Specification," WCAP-10217(NP), June 1983. 3. FSAR, Chapter [IS]. WOG STS Rev. 3.0, 03/31/04 BASES LCO (continued)
APPLICABILITY ACTIONS SURVEILLANCE REQUIREMENTS REFERENCES AFD (RAOC Methodology)
B 3.2.3B The AFD limits are provided in the COLR.Figure B 3.2.3B*1 shows typical RAOC AFD limits.The AFD limits for RAOC do not depend on the target flux difference.
However, the target flux difference may beusedto minimize changes in the axial power distribution.
Violating this LCO on the AFD could produce unacceptable consequences if a Condition 2, 3, or 4 event occurs while the AFD is outside its specified limits.The AFD requirements are applicable in MODE 1 greater than or equal to 50%RTP when the combination of THERMAL POWER and core peaking factors are of primary importance in safety analysis.For AFD limits developed using RAOC methodology, the value of the AFD does not affect the limiting accident consequences with THERMAL POWER<50%RTP and for lower operating power MODES.As an alternative to restoring the AFD to within its specified limits, Required Action A.1 requires a THERMAL POWER reduction to<50%RTP.This places the core in a condition for which the value of the AFD is not important in the applicablesafetyanalyses.
A Completion Time of 30 minutes is reasonable, based on operating experience, to reach 50%RTP without challenging plant systems.SR 3.2.3.1 This Surveillance verifies that theas indicated by the NIS excore channel, is within its specified limits.u.he Surveillance Frequency of 7 days is adequate considering that the AFD is monitoredba computer and any deviation from requirements is alarmed.nse.r-1.WCAP-8403 (nonproprietary),"Power Distribution Control and Load Following Procedures," Westinghouse Electric Corporation, September 1974.2.R.W.Miller et aI.,"Relaxation of Constant Axial Offset Control: Fa Surveillance Technical Specification," WCAP-10217(NP), June 1983.3.FSAR, Chapter[15].WOGSTS B 3.2.3B-3 Rev.3.0, 03/31/04 QPTR B 3.2.4 BASES ACTIONS (continued) that F,(Z), as approximated by F,C(Z) and Fr(Z), and F!~ are within their specified limits within 24 hours of achieving equilibrium conditions at RTP. As an added precaution, if the core power does not reach equilibrium conditions at RTP within 24 hours, but is increased slowly, then the peaking factor surveillances must be performed within 48 hours after increasing THERMAL POWER above the limit of Required Action A.1. These Completion Times are intended to allow adequate time to increase THERMAL POWER to above the limit of Required Action A.l, while not permitting the core to remain with unconfirmed power distributions for extended periods of time. Required Action A.6 is modified by a Note that states that the peaking factor surveillances may only be done after the excore detectors have been normalized to restore QPTR to within limits (i.e., Required Action A.5). The intent of this Note is to have the peaking factor surveillances performed at operating power levels, which can only be accomplished after the excore detectors are normalized to restore QPTR to within limits and the core returned to power.
If Required Actions A.l through A.6 are not completed within their associated Completion Times, the unit must be brought to a MODE or condition in which the requirements do not apply. To achieve this status, THERMAL POWER must be reduced to < 50% RTP within 4 hours. The allowed Completion Time of 4 hours is reasonable, based on operating experience regarding the amount of time required to reach the reduced power level without challenging plant systems.
SURVEILLANCE SR 3.2.4.1 REQUIREMENTS SR 3.2.4.1 is modified by two Notes. Note 1 allows QPTR to be calculated with three power range channels if THERMAL POWER is 5 75% RTP and the input from one Power Range Neutron Flux channel is inoperable. Note 2 allows performance of SR 3.2.4.2 in lieu of SR 3.2.4.1. This Surveillance verifies that the QPTR, as indicated by the Nuclear Instrumentation System (NIS) excore channels, is within its limitsche Frequency of 7 days takes into account other information and alarms available to the operator in the control room.
?zzm WOG STS B 3.2.4-5 Rev. 3.0, 03/31/04 QPTR B 3.2.4 BASES ACTIONS (continued) that Fo(Z), as approximated by Fg(Z)and Ft (2), andH are within their specified limits within 24 hours of achieving equilibrium conditions at RTP.As an added precaution, if the core power does not reach equilibrium conditions at RTP within 24 hours, but is increased slowly, then the peaking factor surveillances must be performed within 48 hours after increasing THERMAL POWER above the limit of Required Action Ai.These Completion Times are intended to allow adequate time to increase THERMAL POWER to above the limit of Required Action A.1, while not permitting thecoreto remain with unconfirmed power distributions for extended periods of time.Required Action A6 is modified by a Note that states that the peaking factor surveillances may only be done after theexcoredetectors have been normalized to restore QPTR to within limits (i.e., Required Action A.5).The intent of this Note is to have the peaking factor surveillances performed at operating power levels, which can only be accomplished after the excore detectors are normalized to restore QPTR to within limits and the core returned to power.If Required Actions Ai through A.6 are not completed within their associated Completion Times, the unit must be brought to a MODE or condition in which the requirements do not apply.To achieve this status, THERMAL POWER must be reduced to<50%RTP within 4 hours.The allowed Completion Time of 4 hours is reasonable, based on operating experience regarding the amount of time required to reach the reduced power level without challenging plant systems.SURVEILLANCE REQUIREMENTS SR 3.2.4.1 SR 3.2.4.1 is modified by two Notes.Note 1 allows QPTR to be calculated with three power range channels if THERMAL POWER is:5 75%RTP and the input from one Power Range Neutron Flux channel is inoperable.
Note 2 allows performance of SR 3.2.4.2 in lieu of SR 3.2.4.1.This Surveillance verifies that the QPTR, as indicated by the Nuclear Instrumentation System (NIS)excore channels, is within its IimitsQhe Frequency of 7 days takes into account other information and alarms available to the operator in the control room.
--._(Insert?)WOGSTS B 3.2.4-5 Rev.3.0, 03/31/04 QPTR B 3.2.4 BASES SURVEILLANCE REQUIREMENTS (continued) For those causes of QPT that occur quickly (e.g., a dropped rod), there typically are other indications of abnormality that prompt a verification of core power tilt. This Surveillance is modified by a Note, which states that it is not required until 12 hours after the input from one or more Power Range Neutron Flux channels are inoperable and the THERMAL POWER is
> 75% RTP. With an NIS power range channel inoperable, tilt monitoring for a portion of the reactor core becomes degraded. Large tilts are likely detected with the remaining channels, but the c ability for detection of small power tilts in some quadrants is decreased,~erforming SR 3.2.4.2 at a Frequency of 12 hours provides an ensuring that any tilt remains within its For purposes of monitoring the QPTR when one power range channel is inoperable, the moveable incore detectors are used to confirm that the normalized symmetric power distribution is consistent with the indicated QPTR and any previous data indicating a tilt.
The incore detector monitoring is performed with a full incore flux map or two sets of four thimble locations with quarter core symmetry.
The two sets of four symmetric thimbles is a set of eight unique detector locations. These locations are C-8, E-5, E-1 I, H-3, H-I 3, L-5, L-1 I, and N-8 for three and four loop cores. The symmetric thimble flux map can be used to generate symmetric thimble "tilt." This can be compared to a reference symmetric thimble tilt, from the most recent full core flux map, to generate an incore QPTR. Therefore, incore monitoring of QPTR can be used to confirm that QPTR is within limits.
With one NIS channel inoperable, the indicated tilt may be changed from the value indicated with all four channels OPERABLE.
To confirm that no change in tilt has actually occurred, which might cause the QPTR limit to be exceeded, the incore result may be compared against previous flux maps either using the symmetric thimbles as described above or a complete flux map. Nominally, quadrant tilt from the Surveillance should be within 2% of the tilt shown by the most recent flux map data. WOG STS B 3.2.4-6 Rev. 3.0, 03/31/04 QPTR B3.2.4 BASES SURVEILLANCE REQUIREMENTS (continued)
For those causes of QPT that occur quickly (e.g., a dropped rod), there typically are other indications of abnormality that prompt a verification of core power tilt.SR 3.2.4.2 This Surveillance is modified by a Note, which states that it is not required until 12 hours after the input from one or more Power Range Neutron Flux channels are inoperable and the THERMAL POWER is>75%RTP.With an NIS power range channel inoperable, tilt monitoring for a portion of the reactor core becomes degraded.Large tilts are likely detected with the remaining channels, but the for detection of small power tilts in some quadrants is decreasedLt>erforming SR 3.2.4.2 at a Frequency of 12 hours provides an accurate alternative me ns for ensuring that any tilt remains within its limits.Ir"'\S2v Z For purposes of monitoring the QPTR when one power range channel is inoperable, the moveable incore detectors are used to confirm that the normalized symmetric power distribution is consistent with the indicated QPTR and any previous data indicating a tilt.The incore detector monitoring isperformedwith a full incore flux map or two sets of four thimble locations with quarter core symmetry.The two sets of four symmetric thimbles is a set of eight unique detector locations.
These locations are C-8, E-5, E-11, H-3, H-13, L-5, L-11, and N-8 for three and four loop cores..The symmetric thimble flux map can be used to generate symmetric thimble"tilt." This can be compared to a reference symmetric thimble tilt, from the most recent full core flux map, to generate an incore QPTR.Therefore, incore monitoring of QPTR can be used to confirm that QPTR is within limits.With one NIS channel inoperable, the indicated tilt may be changed from the value indicated with all four channels OPERABLE.To confirm that no change in tilt has actually occurred, which might cause the QPTR limit to be exceeded, the incore result may be compared against previous flux maps either using the symmetric thimbles as described above or a complete flux map.Nominally, quadrant tilt from the Surveillance should be within 2%of the tilt shown by the most recent flux map data.WOGSTS B 3.2.4-6 Rev.3.0, 03/31/04 RTS Instrumentation B 3.3.1 BASES SURVEILLANCE REQUIREMENTS (continued)
The SRs for each RTS Function are identified by the SRs column of Table 3.3.1-1 for that Function. A Note has been added to the SR Table stating that Table 3.3.1-1 determines which SRs apply to which RTS Functions. Note that each channel of process protection supplies both trains of the RTS. When testing Channel I, Train A and Train B must be examined. Similarly, Train A and Train B must be examined when testing Channel II, Channel Ill, and Channel IV (if applicable). The CHANNEL CALIBRATION and COTS are performed in a manner that is consistent with the assumptions used in analytically calculating the required channel accuracies.
-*+--------------------------------
REVIEWER'S NOTE ------+---------------------------- Certain Frequencies are based on approval topical reports. In order for a licensee to use these times, the licensee must justify the Frequencies as required by the staff SER for the topical report. Performance of the CHANNEL ~~~~~~ncdev~nsures that gross failure of instrumentation has not occurred.
A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the two instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more serious. A CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying that the instrumentation continues to operate properly between each CHANNEL CALIBRATION. Agreement criteria are determined by the unit staff based on a combination of the channel instrument uncertainties, including indication and readability. If a channel is outside the criteria, it may be an indication that the sensor or the signal processing equipment has drifted outside its limit. WOG STS B 3.3.1-49 Rev. 3.0, 03/31/04 RTS Instrumentation B 3.3.1 BASES SURVEILLANCE REQUIREMENTS (continued)
The SRs for each RTS Function are identified by the SRs column of Table 3.3.1-1 for that Function.A Note has been added to the SR Table stating that Table 3.3.1-1 determines which SRs apply to which RTS Functions.
Note that each channel of processprotectionsupplies both trains of the RTS.When testing Channell, Train A and Train B must be examined.Similarly, Train A and Train B must be examined when testing Channel II, Channel III, and Channel IV (if applicable).
The CHANNEL CALIBRATION and COTs are performed in a manner that is consistent with the assumptions used in analytically calculating the required channel accuracies.
-----------------------------------R EV I EW E R'S NOTE Certain Frequencies are based on approval topical reports.In order for a licensee to use these times, the licensee must justify the Frequencies as required by the staff SER for the topical report.SR 3.3.1.1 Performance of the CHANNEL CHECKtQ!1cft'eye;z1 2.ll)IH.i$)ensures that gross failure of instrumentation has not occurred.A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels.It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value.Significant deviations between the two instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more serious.A CHANNEL CHECK will detect gross channel failure;thus, it is key to verifying that the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
Agreement criteria are determined by the unit staff based on a combination of the channel instrument uncertainties, inclUding indication and readability.
If a channel is outside the criteria, it may be an indication that the sensor or the signal processing equipment has drifted outside its limit.WOG STS B 3.3.1-49 Rev.3.0, 03/31/04 RTS Instrumentation B 3.3.1 BASES -- '1 SURVEILLANCE REQUIREMENTS (continued)
Lj? I 2 h wry .G Le Frequency is based onzeratins experience that demonstrates channel failure is rare. The CHANNEL CHECK supplements less formal, but more frequent, checks of channels during normal operational use of the displays associated with the LC0 required channe SR 3.3.1.2 compares the ca lance calculation to the power range channel output If the calorimetric heat balance calculation results exceed the power range channel output by more than 2% RTP, the power range channel is not declared inoperable, but must be adjusted.
The power range channel output shall be adjusted consistent with the calorimetric heat balance calculation results if the calorimetric calculation exceed the power range channel output by more than + 2% RTP. If the power range channel output cannot be properly adjusted, the channel is declared inoperable.
If the calorimetric is performed at part power
(< [70]% RTP), adjusting the power range channel indication in the increasing power direction will assure a reactor trip below the safety analysis limit
(< [I 181% RTP). Making no adjustment to the power range channel in the decreasing power direction due to a part power calorimetric assures a reactor trip consistent with the safety analyses. This allowance does not preclude making indicated power adjustments, if desired, when the calorimetric heat balance calculation is less than the power range channel output.
To provide close agreement between indicated power and to preserve operating margin, the power range channels are normally adjusted when operating at or near full power during steady-state conditions. However, discretion must be exercised if the power range channel output is adjusted in the decreasing power direction due to a part power calorimetric
(< [70]% RTP). This action may introduce a non-conservative bias at higher power levels which may result in an NIS reactor trip above the safety analysis limit ( > [I 181% RTP). The cause of the potential non-conservative bias is the decreased accuracy of the calorimetric at reduced power conditions.
The primary error contributor to the instrument uncertainty for a secondary side power calorimetric measurement is the feedwater flow measurement, which is typically a AP measurement across a feedwater venturi. While the measurement uncertainty remains constant in AP as power decreases, when translated into flow, the uncertainty increases as a square term.
Thus a 1% flow error at 100&deg;/o power can approach a 10%
flow error at WOG STS B 3.3.1-50 Rev. 3.0, 03/31/04 RTS Instrumentation B 3.3.1 BASES/-SURVEILLANCE REQUIREMENTS (continued)
!(l r 1.2.h
[ipe based on experience that demonstrates channel failure is rare.The CHANNEL CHECK supplements less formal, but more frequent, checks of channels during normal operational use of the displays associated with the LCO required SR 3.3.1.2 calculation to the power range channel output v 4 h If the calorimetric heat balance calculation results exceed the power range channel output by more than 2%RTP, the power range channel is not declared inoperable, but must be adjusted.The power range channel output shall be adjusted consistent with the calorimetric heat balance calculation results if the calorimetric calculation exceed the power range channel output by more than+2%RTP.If the power range channel output cannot be properly adjusted, the channel is declared inoperable.
If the calorimetric is performed at part power<<[70]%RTP), adjusting the power range channel indication in the increasing power direction will assure a reactor trip below the safety analysis limit<<[118J%RTP).Making no adjustment to the power range channel in the decreasing power direction due to a part power calorimetric assures a reactor trip consistent with the safety analyses.This allowance does not preclude making indicated power adjustments, if desired, when the calorimetric heat balance calculation is less than the power range channel output.To provide close agreement between indicated power and to preserve operating margin, the power range channels are normally adjusted when operating at or near full power during steady-state conditions.
However, discretion must be exercised if the power range channel output is adjusted in the decreasing power direction due to a part power calorimetric
<<[70J%RTP).This action may introduce a non-conservative bias at higher power levels which may result in an NIS reactor trip above the safety analysis limit (>[118J%RTP).The cause of the pbtential non-conservative bias is the decreased accuracy of the calorimetric at reduced power conditions.
The primary error contributor to the instrument uncertainty for a secondary side power calorimetric measurement is the feedwater flow measurement, which is typically a liP measurement across a feedwater venturi.While the measurement uncertainty remains constant in i1P as power decreases, when translated into flow, the uncertainty increases as a square term.Thusa1%flow error at 100%power can approach a 10%flow error at WOG STS B 3.3.1-50 Rev.3.0, 03/31/04 RTS Instrumentation B 3.3.1 BASES SURVEILLANCE REQUIREMENTS (continued) 30% RTP even though the AP error has not changed. An evaluation of extended operation at part power conditions would conclude that it is prudent to administratively adjust the setpoint of the Power Range Neutron Flux - High bistables to 5 [85]% RTP when: 1) the power range channel output is adjusted in the decreasing power direction due to a part power calorimetric below
[70]% RTP; or 2) for a post refueling startup.
The evaluation of extended operation at part power conditions would also conclude that the potential need to adjust the indication of the Power Range Neutron Flux in the decreasing power direction is quite small, primarily to address operation in the intermediate range about P-10 (nominally 10%
RTP) to allow enabling of the Power Range Neutron Flux - Low setpoint and the Intermediate Range Neutron Flux reactor trips. Before the Power Range Neutron Flux - High bistables are reset to 5 [log]% RTP, the power range channel adjustment must be confirmed based on a calorimetric performed at 2 [70]% RTP. +--------------+-------------**----
REVIEWER'S NOTE ...................................
A plant specific evaluation based on the guidance in Westinghouse Technical Bulletin ESBU-TB-92-14 is required to determine the power level below which power range channel adjustments in a decreasing power direction become a concern. This evaluation must reflect the plant specific RTS setpoint study. In addition, this evaluation should determine if additional administrative controls are required for Power Range Neutron Flux-High trip setpoint setting changes The Note clarifies that this Surveillance is required only if reactor power is 2 15% RTP and that 12 hours are allowed for performing the first Surveillance after reaching 15% RTP.
A power level of 15% RTP is chosen based on plant stability, i.e., automatic rod control capability and turbine generator synchronized to the grid.
@e Frequency of every 24 hours is adequate. It is based on unit operating experience, considering instrument reliability and operating history data for instrument drift. Together these factors demonstrate that a difference between the calorimetric heat balance calculation and the power range channel output of more than
+2% RTP is not any 24 hour period.
In addition, control room operators periodically monitor indications and alarms to detect deviations in channel outputs.
WOG STS B 3.3.1-51 Rev. 3.0, 03/31/04 RTS Instrumentation B 3.3.1 BASES SURVEILLANCE REQUIREMENTS (continued) 30%HTP even though the llP error has not changed.An evaluation of extended operation at part power conditions would conclude that it is prudent to administratively adjust the setpoint of the Power Range Neutron Flux-High bistables to$[85]%RTP when: 1)the power range channel output is adjusted in the decreasing power direction due to a part power calorimetric below[70]%RTP;or 2)for a post refueling startup.The evaluation of extended operation at part power conditions would also conclude that the potential need to adjust the indication of the Power Range Neutron Flux in the decreasing power direction is quite small, primarily to address operation in the intermediate range about P-10 (nominally 10%RTP)to allow enabling of the Power Range Neutron Flux-Low setpoint and the Intermediate Range Neutron Flux reactor trips.Before the Power Range Neutron Flux-High bistables are reset to$[109]%RTP, the power range channel adjustment must be confirmed based on a calorimetric performed at<::[70]%RTP.
REV I EWE R'S NOTE A plant specific evaluation based on the guidance in Westinghouse Technical Bulletin ESBU-TB-92-14 is required to determine the power level below which power range channel adjustments in a decreasing power direction become a concern.This evaluation must reflect the plant specific RTS setpoint study.In addition, this evaluation should determine if additional administrative controls are required for Power Range Neutron Flux-High trip setpoint setting changes The Note clarifies that this Surveillance is required only if reactor power is<:: 15%RTP and that 12 hours are allowed for performing the first Surveillance after reaching 15%RTP.A power level of 15%RTP is chosen based on plant stability, i.e., automatic rod control capability and turbine generator synchronized to the grid.[ihe Frequency of every 24 hours is adequate.It is based on unit operating experience, considering instrument reliability and operating history data for instrument drift.Together these factors demonstrate that a difference between the calorimetric heat balance calculation and the power range channel output of more than+2%RTP is not expected i I------r_any 24 hour period.
In addition, control room operators periodically monitor redundant indications and alarms to detect deviations in channel outputs.WOGSTS B 3.3.1-51 Rev.3.0, 03/31/04 RTS Instrumentation B 3.3.1 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.1.3 compares the incore system to the NIS channelIf the absolute difference is3%, the NIS channel is still OPERABLE, but must be readjusted.
The excore NIS channel shall be adjusted if the absolute difference between the incore and excore AFD isIf the NIS channel cannot be properly readjusted, the channel is declared inoperable.
This Surveillance is performed to verify the input to the overtemperature Function.A Note clarifies that the Surveillance is required only if reactor power is[15%]RTP and that 24 hours is allowed for performing the first Surveillance after reaching[15%]RTP.[fhe Frequency of every 31 EFPD is adequate.It is based on unit operating experience, considering instrument reliability and operating history data for instrument drift.Also, the slow changes in neutron flux during the fuel cycle can be detected during this interval.SR 3.3.1.4 SR 3.3.1.4 is the performance of a TADOT62#}1s&#xa2;aJ MSIS.This test shall veny OPERABILITY by actuation of the end devices.A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable TADOT of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.TheRTB test shall include separate verification of the undervoltage and shunt trip mechanisms.
Independent verification of RTB undervoltage and shunt trip Function is not required for the bypass breakers.No capability is provided for performing such a test at power.The independent test for bypass breakers is included in SR 3.3.1.14.The bypass breaker test shall include a local shunt trip.A Note has been added to indicate that this test must be performed on the bypass breaker prior to placing it in service.WOG STS B 3.3.1-52 Rev.3.0, 03/31/04 RTS Instrumentation B 3.3.1 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.1.3 compares the incore system to the NIS channelIf the absolute difference is3%, the NIS channel is still OPERABLE, but must be readjusted.
The excore NIS channel shall be adjusted if the absolute difference between the incore and excore AFD isIf the NIS channel cannot be properly readjusted, the channel is declared inoperable.
This Surveillance is performed to verify the input to the overtemperature Function.A Note clarifies that the Surveillance is required only if reactor power is[15%]RTP and that 24 hours is allowed for performing the first Surveillance after reaching[15%]RTP.[fhe Frequency of every 31 EFPD is adequate.It is based on unit operating experience, considering instrument reliability and operating history data for instrument drift.Also, the slow changes in neutron flux during the fuel cycle can be detected during this interval.SR 3.3.1.4 SR 3.3.1.4 is the performance of a TADOT62J!lYs&#xa2;aJ C2:T)l6GEr<W!EST mls.This test shall veny OPERABILITY by actuation of the end devices.A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable TADOT of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.TheRTB test shall include separate verification of the undervoltage and shunt trip mechanisms.
Independent verification of RTB undervoltage and shunt trip Function is not required for the bypass breakers.No capability is provided for performing such a test at power.The independent test for bypass breakers is included in SR 3.3.1.14.The bypass breaker test shall include a local shunt trip.A Note has been added to indicate that this test must be performed on the bypass breaker prior to placing it in service.WOG STS B 3.3.1-52 Rev.3.0, 03/31/04 RTS Instrumentation B 3.3.1 BASES SURVEILLANCE REQUIREMENTS (continued)
G.he Frequency of every 62 days on a STAGGERED TEST BASIS is Justified in Reference 13.:0 SR 3.3.1.5 SR 3.3.1.5 is the performance of an ACTUATION LOGIC TEST.The SSPS is tested*YJ?"9 92#y@'a S@GEREDkEST the semiautomatic tester.The train being tested is placed in the bypass condition, thus preventing inadvertent actuation.
Through the semiautomatic tester, all possible logic combinations, with and without applicable permissives, are tested for each protection operation of the P-7 permissive which is a logic function only.Llhe Frequency of every 92 days on a STAGGERED TEST BASIS IS justified in Reference 13.--n.nSer t=:.D SR 3.3.1.6 SR 3.3.1.6 is a calibration of the excore channels to the incore channels.If the measurements do not agree, the excore channels are not declared inoperable but must be calibrated to agree with the incore detector measurements.
If the excore channels cannot be adjusted, the channels are declared inoperable.
This Surveillance is performed to verify the input to the overtemperatureT Function.A Note modifies SR 3.3.1.6.The Note states that this Surveillance is required only if reactor power is>50%RTP and that[24J hours is allowed for performing the first surveillance after reaching 50%RTP.[he Frequency of 92 EFPD is adequate.It is based on industry operating experience, considering instrument reliability and operating history data for instrument drift.
D WOGSTS B 3.3.1-53 Rev.3.0, 03/31/04 RTS Instrumentation B 3.3.1 BASES SURVEILLANCE REQUIREMENTS (continued)
G.he Frequency of every 62 days on a STAGGERED TEST BASIS is Justified in Reference 13.fC-.-Vn.geY'ill SR 3.3.1.5 SR 3.3.1.5 is the performance of an ACTUATION LOGIC TEST.The SSPS is tested 6'#9 924y&sect;a S@GEREDkEST the semiautomatic tester.The train being tested is placed in the bypass condition, thus preventing inadvertent actuation.
Through the semiautomatic tester, all possible logic combinations, with and without applicable permissives, are tested for each protection operation of the P-7 permissive which is a logic function only.ll.he Frequency of every 92 days on a STAGGERED TEST BASIS IS justified in Reference 13.-t=:.i)SR 3.3.1.6 SR 3.3.1.6 is a calibration of the excore channels to the incore channels.If the measurements do not agree, the excore channels are not declared inoperable but must be calibrated to agree with the incore detector measurements.
If the excore channels cannot be adjusted, the channels are declared inoperable.
This Surveillance is performed to verify the input to the overtemperatureT Function.A Note modifies SR 3.3.1.6.The Note states that this Surveillance is required only if reactor power is>50%RTP and that[24]hours is allowed for performing the first surveillance after reaching 50%RTP.[he Frequency of 92 EFPD is adequate.It is based on industry operating experience, considering instrument reliability and operating history data for instrument drift.
D WOGSTS B 3.3.1-53 Rev.3.0, 03/31/04 RTS Instrumentation B 3.3.1 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.1.7 is the performance of a COT@-$. A COT is performed on each required channel to ensure the entire channel will perform the intended Function.
A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable COT of a relay.
This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions. Setpoints must be within the Allowable Values specified in Table 3.3.1-1 The difference between the current "as found" values and the previous test "as left" values must be consistent with the drift allowance used in the setpoint methodology. The setpoint shall be left set consistent with the assumptions of the current unit specific setpoint methodology.
The "as found" and "as left" values must also be recorded and reviewed for consistency with the assumptions of Reference
: 9. SR 3.3.1.7 is modified by a Note that provides a 4 hours delay in the requirement to perform this Surveillance for source range instrumentation when entering MODE 3 from MODE 2. This Note allows a normal shutdown to proceed without a delay for testing in MODE 2 and for a short time in MODE 3 until the RTBs are open and SR 3.3.1.7 is no longer required to be performed.
If the unit is to be in MODE 3 with the RTBs closed for
> 4 hours this Surveillance must be performed prior to 4 hours after entry into MODE 3. t Frequency of 184 days is justified in Reference
: 9. --+- (xnsem WOG STS B 3.3.1-54 Rev. 3.0, 03/31/04 RTS Instrumentation B 3.3.1 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.1.7 SR 3.3.1.7 is the performance of a A COT is performed on each required channel to ensure the entire channel will perform the intended Function.A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable COT of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
Setpoints must be within the Allowable Values specified in Table 3.3.1-1.The difference between the current"as found" values and the previous test"as left" values must be consistent with the drift allowance used in the setpoint methodology.
The setpoint shall be left set consistent with the assumptions of the current unit specific setpoint methodology.
The"as found" and"as left" values must also be recorded and reviewed for consistency with the assumptions of Reference 9.SR 3.3.1.7 is modified by a Note that providesa4 hours delay in the requirement to perform this Surveillance for source range instrumentation when entering MODE 3 from MODE 2.This Note allows a normal shutdown to proceed without a delay for testing in MODE 2 and for a short time in MODE 3 until the RTBs are open and SR 3.3.1.7 is no longer required to be performed.
If the unit is to be in MODE 3 with the RTBs closed for>4 hours this Surveillance must be performed prior to 4 hours after entry into MODE 3.E;e Frequency of 184 days is justified in Reference 9.(1:n.ser t Z.-WaG STS B 3.3.1-54 Rev.3.0, 03/31/04 RTS Instrumentation B 3.3.1 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.1.8 SR 3.3.1.8 is the performance of a COT as described in SR 3.3.1.7, except it is modified by a Note that this test shall include verification that the P-6 and P-10 interlocks are in their required state for the existing unit condition.
A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable COT of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
The Frequency is modified by a Note that allows this surveillance to be satisfied if it has been performed within 1 84 the Frequencies prior to reactor startup and four hours after reducing power below P-10 and P-6.The Frequency of"prior to startup" ensures this surveillance is performed prior to critical operations and applies to the source, intermediate and power range low instrument channels.The Frequency of[12J hours after reducing power below P-10 (applicable to intermediate and power range low channels)and 4 hours after reducing power below P-6 (applicable to source range channels)allows a normal shutdown to be completed and the unit removed from the MODE of Applicability for this surveillance without a delay to erfor e testing required by this surveillance.
The Frequenc 0v2 cia s hereafter applies if the plant remains in the MODE of Appllc t tty after the initial performances of prior to reactor startup and[12J and four hours after reducing power below P-10 or P-6, respectively.
The MODE of Applicability for this surveillance is<P-10 for the power range low and intermediate range channels and<P-6 for the source range channels.Once the unit is in MODE 3, this surveillance is no longer required.If power is to be maintained
<P-10 for more than[12J hours or<P-6 for more than 4 hours, then the testing required by this surveillance must be performed prior to the expiration of the time limit.[TwelveJ hours and four hours are reasonable times to complete the required testing or place the unit in a MODE where this surveillance is no longer required.This test ensures that the NIS source, intermediate, and power range low channels areOPERABLEprior to taking the reactor critical and after reducing power into the MODE<<P-10 or<P-6)for periods>[12J and 4 hours, respectively.l2:.he Frequency of 184 days is justified in Reference 13.WOGSTS B 3.3.1-55 Rev.3.0, 03/31/04 RTS Instrumentation B 3.3.1 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.1.8 SR 3.3.1.8 is the performance of a COT as described in SR 3.3.1.7, except it is modified by a Note that this test shall include verification that the P-6 and P-10 interlocks are in their required state for the existing unit condition.
A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable COT of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
The Frequency is modified by a Note that allows this surveillance to be satisfied if it has been performed within 1 84 the Frequencies prior to reactor startup and four hours after reducing power below P-10 and P-6.The Frequency of"prior to startup" ensures this surveillance is performed prior to critical operations and applies to the source, intermediate and power range low instrument channels.The Frequency of[12J hours after reducing power below P-10 (applicable to intermediate and power range low channels)and 4 hours after reducing power below P-6 (applicable to source range channels)allows a normal shutdown to be completed and the unit removed from the MODE of Applicability for this surveillance without a delay to erfor e testing required by this surveillance.
The Frequenc 0v2 cia s hereafter applies if the plant remains in the MODE of Applic t tty after the initial performances of prior to reactor startup and[12]and four hours after reducing power below P-10 or P-6, respectively.
The MODE of Applicability for this surveillance is<P-10 for the power range low and intermediate range channels and<P-6 for the source range channels.Once the unit is in MODE 3, this surveillance is no longer required.If power is to be maintained
<P-10 for more than[12J hours or<P-6 for more than 4 hours, then the testing required by this surveillance must be performed prior to the expiration of the time limit.[Twelve]hours and four hours are reasonable times to complete the required testing or place the unit in a MODE where this surveillance is no longer required.This test ensures that the NIS source, intermediate, and power range low channels are OPERABLE prior to taking the reactor critical and after reducing power into the MODE<<P-10 or<P-6)for periods>[12J and 4 hours, respectively.\1.he Frequency of 184 days is justified in Reference 13.WOGSTS B 3.3.1-55 Rev.3.0, 03/31/04 RTS Instrumentation B 3.3.1 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.1.9 is the performance of a TADOT and& performed every
[92] days, as justified in Reference 9$A successful test of the required contact(s) ot a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable TADOT of a relay.
This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
The SR is modified by a Note that excludes verification of setpoints from the TADOT. Since this SR applies to RCP undervoltage and underfrequency relays, setpoint verification requires elaborate bench calibration and is accomplished during the CHANNEL CALIBRATION.
verifies that the channel responds to a measured parameter within the necessary range and accuracy. CHANNEL CALIBRATIONS must be performed consistent with the
 
assumptions of the unit specific setpoint methodology. The difference between the current "as found" values and the previous test "as left" values must be consistent with the drift allowance used in the setpoint methodology.
Ge Frequency of 18 months is based on the assumption of an 18 month calibration interval in the determination of the magnitude of equipment drift in the setpoint methodology.
a$--- . . ..-.". -t ;cS - SR 3.3.1.10 is modified by a Note stating that this test shall include verification that the time constants are adjusted to the prescribed values where applicable.
WOE STS B 3.3.1-56 Rev. 3.0, 03/31/04 RTS Instrumentation B 3.3.1 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.1.9 SR 3.3.1.9 is the performance of a TADOTperformed every[92]days, as justified in Reference 9.A successful test of the required contac s 0 a cannel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable TADOT of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
The SR is modified by a Note that excludes verification of setpoints from the TADOr.Since this SR applies to RCP undervoltage and underfrequency relays, setpoint verification requires elaborate bench calibration and is accomplished during the CHANNEL CALIBRATION.
SR 3.3.1.10 A CH'--EC ap oximately at CAOBRATId1\riSa compeec ec 0 e'Instrument loop, including the sensor.The test verifies that the channel responds to a measured parameter within the necessary range and accuracy.CHANNEL CALIBRATIONS must be performed consistent with the assumptions of the unit specific setpoint methodology.
The difference between the current"as found" values and the previous test"as left" values must be consistent with the drift allowance used in the setpoint methodology. Frequency of 18 months is based on the assumption of an 18 month calibration interval in the determination of the magnitude of equipment drift in the setpoint methodology.....
SR 3.3.1.10 is modified by a Note stating that this test shall include verification that the time constants are adjusted to the prescribed values where applicable.
WOG STS B 3.3.1-56 Rev.3.0, 03/31/04 RTS Instrumentation B 3.3.1 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.1.1 1 is the performance of a CHANNEL CALIBRATION, as described in SR 3.3.1.10&vev$
[I81 muhths) This SR is modified by a Note stating that neutron detectors are excluded from the CHANNEL CALIBRATION. The CHANNEL CALIBRATION for the power range neutron detectors consists of a normalization of the detectors based on a power calorimetric and flux map performed above 15% RTP. The CHANNEL CALIBRATION for the source range and intermediate range neutron detectors consists of obtaining the detector plateau or preamp discriminator curves, evaluating those curves, and comparing the curves to the manufacturer's data. This Surveillance is not required for the NIS power range detectors for entry into MODE 2 or 1, and is not required for the NIS intermediate range detectors for entry into MODE 2, because the unit must be in at least MODE 2 to perform the test for the in mediate range detectors and MODE 1 for the power range detectors. The r [I81 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power. Operating experience has shown these components usually pass the on the [18] month Frequency.
.(e;-----
SR 3.3.1.12'is the performance of a CHANNEL CALIBRATION, as described in SR 3.3.1.1$e_\~er~[18]
flth3. This SR is modified by a Note stating that this test shall include veification of the RCS resistance temperature detector (RTD) bypass loop flow rate. Whenever a sensing element is replaced, the next required CHANNEL CALIBRATION of the resistance temperature detectors (RTD) sensors is accomplished by an inplace cross calibration that compares the other sensing elements with the recently installed sensing element. This test will verify the rate lag compensation for flow from the core to the RTDs. Ehe Frequency is justified by the assumption of an 18 month calibration Interval in the determination of the magnitude of equipment drift in the setpoint analysis.
WOG STS B 3.3.1 -57 Rev. 3.0, 03/31/04 RTS Instrumentation B 3.3.1 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.1.11 SR 3.3.1.11 is the performance of a CHANNEL CALIBRATION, as described in SR 3.3.1.1D&Ililo1Jth5:l This SR is modified by a Note stating that neutron detectors are excluded from the CHANNEL CALIBRATION.
The CHANNEL CALIBRATION for the power range neutron detectors consists of a normalization of the detectors based on a power calorimetric and flux map performed above 15%RTP.The CHANNEL CALIBRATION for the source range and intermediate range neutron detectors consists of obtaining the detector plateau or preamp discriminator curves, evaluating those curves, and comparing the curves to the manufacturer's data.This Surveillance is not required for the NIS power range detectors for entry into MODE 2 or 1, and is not required for the NIS intermediate range detectors for entry into MODE 2, because the unit must be in at least MODE 2 to perform the test for the range detectors and MODE 1 for the power range detectors.l1.he
[18]month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power.Operating experience has shown these components usually pass the Surveillance wh;-r.en on the[18]month Frequency.
SR 3.3.1.12 SR 3.3.1.1iis the performance of a CHANNEL CALIBRATION, as described in SR 3.3.1.1 r.(
This SR is modified by a Note stating that this test shall inclu everification of the RCS resistance temperature detector (RTD)bypass loop flow rate.Whenever a sensing element is replaced, the next required CHANNEL CALIBRATION of the resistance temperature detectors (RTD)sensors is accomplished by an inplace cross calibration that compares the other sensing elements with the recently installed sensing element.This test will verify the rate lag compensation for flow from the core to the RTDs.["!;e Frequency is justified by the assumption of an 18 month calibration Interval in the determination of the magnitude of equipment drift in the setpoint analysis.
1])WOGSTS B 3.3.1-57 Rev.3.0, 03/31/04 RTS Instrumentation B 3.3.1 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.1.13 is the performance of a COT of RTS interlocks-(-4. A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable COT of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable - *" ""~"-- extensions.
J -..- _. - --.- ----* khe ~re~uenc* based on the known reliability of the interlocks and the multichannel redundancv available, and has been shown to be acceptable through operating experience.
+ r-1 SR 3.3.1.14 is the performance of a TADOT of the Manual Reactor Trip, RCP Breaker Position, and the SI Input from ESFAS.
A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable TADOT of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical S~ecifications and non-Technical ssecifications tests at least once ser refueling interval with applicable extensions.
MAW is) gemed evml8J ___I ~hsi The test shall independently verify the OPERABILITY of the undervoltage and shunt trip mechanisms for the Manual Reactor Trip Function for the Reactor Trip Breakers and Reactor Trip Bypass Breakers. The Reactor Trip Bypass Breaker test shall include testing of the automatic undervoltage trip.
-" c-&ZeTuencj~s based on the known reliability of the Functions and the multichannel redundancy available, and has been shown to be acceptable through operating experience.
The SR is modified by a Note that excludes verification of setpoints from the TADOT.
The Functions affected have no setpoints associated with them. WOG STS B 3.3.1-58 Rev. 3.0, 03/31/04 RTS Instrumentation B 3.3.1 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.1.13 SR 3.3.1.13 is the performance of a COT of RTS Q'jjffll&sect;'tf@
A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable COT of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions. h)O[he reliability of the interlocks and the multichannel redundancy available, and has been shown to be acceptable through operating experience.I:'l eve 2:J SR 3.3.1.14 SR 3.3.1.14 is the performance of a TADOT of the Manual Reactor Trip, RCP Breaker Position, and the Sl/nput from ESFAS.A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable TADOT of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least on e er refuelin interval with applicable extensions.
e edev 18 rT1,Pf'1'ths The test shall independently verify the OPERABILITY of the underVoltage and shunt trip mechanisms for the Manual Reactor Trip Function for the Reactor Trip Breakers and Reactor Trip Bypass Breakers.The Reactor Trip Bypass Breaker test shall include testing of the automatic undervoltage trip.6!!g based on the known reliability of the Functions and the multichannel redundancy available, and has been shown to be acceptable through operating experience.
--...-,.,.
The SR is modified by a Note that excludes verification of setpoints from the TADOr.The Functions affected have no setpoints associated with them.WOGSTS B 3.3.1-58 Rev.3.0, 03/31/04 RTS Instrumentation B 3.3.1 BASES SURVEILLANCE REQUIREMENTS (continued) Response time may be verified by actual response time tests in any series of sequential, overlapping or total channel measurements, or by the summation of allocated sensor, signal processing and actuation logic response times with actual response time tests on the remainder of the channel. Allocations for sensor response times may be obtained from: (1) historical records based on acceptable response time tests (hydraulic, noise, or power interrupt tests), (2) in place, onsite, or offsite (e.g., vendor) test measurements, or (3) utilizing vendor engineering specifications.
WCAP-13632-P-A, Revision 2, "Elimination of Pressure Sensor Response Time Testing Requirements," (Ref. 10) provides the basis and methodology for using allocated sensor response times in the overall verification of the channel response time for specific sensors identified in the WCAP. Response time verification for other sensor types must be demonstrated by test. [WCAP-14036-P, Revision 1, "Elimination of Periodic Protection Channel Response Time Tests," (Ref. 15) provides the basis and methodology for using allocated signal processing and actuation logic response times in the overall verification of the protection system channel response time.] The allocations for sensor, signal conditioning, and actuation logic response times must be verified prior to placing the component in operational service and re-verified following maintenance that may adversely affect response time.
In general, electrical repair work does not impact response time provided the parts used for repair are of the same type and value. Specific components identified in the WCAP may be replaced without verification testing. One example where response time could be affected is replacing the sensing assembly of a transmitter. appropriate, each channel's response must be verified every 181 months on a STAGGERED TEST BASIS. Testing of the final actuation devices is included in the testing. Response times cannot be determined during unit operation because equipment operation is required to measure response times. Experience has components usually pass this surveillance when performed at the 18 months Frequency.
Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.
G---.- SR 3.3.1.16 is modified by a Note stating that neutron detectors are excluded from RTS RESPONSE TIME testing. This Note is necessary because of the difficulty in generating an appropriate detector input signal. Excluding the detectors is acceptable because the principles of detector operation ensure a virtually instantaneous response.
WOG STS B 3.3.1-60 Rev. 3.0, 03/31/04 RTS Instrumentation B 3.3.1 BASES SURVEILLANCE REQUIREMENTS (continued)
Response time may be verified by actual response time tests in any series of sequential, overlapping or total channel measurements, or by the summation of allocated sensor, signal processing and actuation logic response times with actual response time tests on the remainder of the channel.Allocations for sensor response times may be obtained from: (1)historical records based on acceptable response time tests (hydraulic, noise, or power interrupt tests), (2)in place, onsite, or offsite (e.g., vendor)test measurements, or (3)utilizing vendor engineering specifications.
WCAP-13632-P-A, Revision 2,"Elimination of Pressure Sensor Response Time Testing Requirements," (Ref.10)provides the basis and methodology for using allocated sensor response times in the overall verification of the channel response time for specific sensors identified in the WeAP.Response time verification for other sensor types must be demonstrated by test.[WCAP-14036-P, Revision 1,"Elimination of Periodic Protection Channel Response Time Tests," (Ref.15)provides the basis and methodology for using allocated signal processing and actuation logic response times in the overall verification of the protection system channelresponsetime.]
The allocations for sensor, signal conditioning, and actuation logic response times must be verified prior to placing the component in operational service and re-verified following maintenance that may adversely affect response time.In general, electrical repair work does not impact response time provided the parts used for repair are of the same type and value.Specific components identified in the WCAP may be replaced without verification testing.One example where response time could be affected is replacing the sensing assembly of a transmitter.
rAs appropriate, each channel's response must be verified every'118]months on a STAGGERED TEST BASIS.Testing of the final actuation devices is included in the testing.Response times cannot be determined during unit operation because equipment operation is required to measure response times.Experience has shown that these components usually pass thissurveillancewhen performed at the 18 months Frequency.
Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.SR 3.3.1.16 is modified by a Note stating that neutron detectors are excluded from RTS RESPONSE TIME testing.This Note is necessary because of the difficulty in generating an appropriate detector input signal.Excluding the detectors is acceptable because the principles of detector operation ensure a virtually instantaneous response.WOG STS B 3.3.1-60 Rev.3.0, 03/31/04 Engineered Safety Feature Actuation System (ESFAS) Instrumentation B 3.3.2 BASES SURVEILLANCE
............................
REVIEWER'S NOTE ................................
*------- REQUIREMENTS In Table 3.3.2-1, Functions 7.b and 7.c were not included in the generic evaluations approved in either WCAP-10271, as supplemented, or WCAP-14333.
In order to apply the WCAP-10271, as supplemented, and WCAP-14333 TS relaxations to plant specific Functions not evaluated generically, licensees must submit plant specific evaluations for NRC review and approval.
----------------------d---**--"---------------------------------------------------------*--------" The SRs for each ESFAS Function are identified by the SRs column of Table 3.3.2-1. A Note has been added to the SR Table to clarify that Table 3.3.2-1 determines which SRs apply to which ESFAS Functions. Note that each channel of process protection supplies both trains of the ESFAS. When testing channel I, train A and train B must be examin+. Similarly, train A and train B must be examined when testing channel 11, channel Ill, and channel IV (if applicable). The CHANNEL CALIBRATION and COTS are performed in a manner that is consistent with the
~ assumptions used in analytically calculating the required channel accuracies.
-----------------------------REVIEWER'S NOTE ......................................... Certain Frequencies are based on approved topical reports. In order for a licensee to use these times, the licensee must justify the Frequencies as required by the staff SER for the topical report. Performance of the CHANNEL CHECK^^ kverd17Pursknsures that a gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the two instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more serious. A CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
WOG STS -- - Rev. 3.0, 03131104 BASES SURVEILLANCE REQUIREMENTSEngineeredSafety Feature Actuation System (ESFAS)Instrumentation B 3.3.2----------------------------R EVI EWER'S NOTE In Table 3.3.2-1, Functions 7.b and 7.c were not included in the generic evaluations approved in either WCAP-1 0271, as supplemented, or WCAP-14333.
In order to apply the WCAP-10271
, as supplemented, and WCAP-14333 TS relaxations to plant specific Functions not evaluated generically, licensees must submit plant specific evaluations for NRC review and approval.The SRs for each ESFAS Function are identified by the SRs column of Table 3.3.2-1.A Note hasbeenadded to the SR Table to clarify that Table 3.3.2-1 determines which SRs apply to which ESFAS Functions.
Note that each channel of process protection supplies both trains of the ESFAS.When testing channell, train A and train B must be Similarly, train A and train B must be examined when testing channel!II, channell".
and channell': (if applicable).
The CALIBRATION and COTs are performed In a manner that IS consistent with the I assumptions used in analytically calculating the required channel accuracies.
-----------------------------REVI EWE R'S NOTE Certain Frequencies are based on approved topical reports.In order for a licensee to use these times, the licensee must justify the Frequencies as required by the staff SER for the topical report.WOGSTS B 3.3.2-48 Rev.3.0, 03/31/04 Engineered Safety Feature Actuation System (ESFAS)Instrumentation B 3.3.2 BASES SURVEILLANCE REQUIREMENTS (continued)
Agreement criteria are determined by the unit staff, based on a combination of the channel instrument uncertainties, including indication and reliability.
If a channel is outside the criteria, it may be an indication that the sensor or the signal processing equipment has drifted outside its limit. Frequency is based on operating experience that demonstrates channel failure is rare.The CHANNEL CHECK supplements less formal, but more frequent, checks of channels duringnormaloperational use of the displays associated with the LCO required channels.
SR 3.3.2.2 cr.'SR 3.3.2.2 is the erformance of an ACTUATION LOGICSs tested on a S1,AeGERED T__using the semiautomatic tester.e train being tested is placed in the bypass condition, thus preventing inadvertent actuation.
Through the semiautomatic tester, all possible logic combinations, with and without applicable permissives, are tested for each protection function.In addition, the master relay coil is pulse tested for continuity.Thisverifies that the logic modules are that there is an intact voltage signal path to the master relay coils.[tle Frequency of every 92 days on a STAGGERED TEST BASIS is justified in Referencet')
SR 3.3.2.3 SR 3.3.2.3 is the performance of an ACTUATION LOGIC TEST as described in SR 3.3.2.2, except that the semiautomatic tester is not used and the continuity check does not have to be performed, as explained in the Note.This SR is applied to the balance of plant actuation logic and relays that do not have the SSPS test circuits installed to utilize the semiautomatic tester or perform the continuity che.cK, test is also performed every 31 days on a STAGGERED TEST BASI$.The Frequency is adequate based on industry operating experience, considering instrument reliability and operating history data.CL*..
WOGSTS B 3.3.2-49 Rev.3.0, 03/31/04 Engineered Safety Feature Actuation System (ESFAS)Instrumentation B 3.3.2 BASES SURVEILLANCE REQUIREMENTS (continued)
Agreement criteria are determined by the unit staff, based on a combination of the channel instrument uncertainties, including indication and reliability.
If a channel is outside the criteria, it may be an indication that the sensor or the signal processing equipment has drifted outside its limit.&sect;e Frequency is based on operating experience that demonstrates channel failure is rare.The CHANNEL CHECK supplements less formal, but more frequent, checks of channels during normal operational use of the displays associated with the LCOrequiredchannels.crr-.....r**1 S.:..X\or"-SR 3.3.2.2 cr.'SR 3.3.2.2 is the erformance of an ACTUATION LOGIC TEST/@)Ss tested on a S"'(AeGERED
"'[.using the semiautomatic tester.e train being tested is placed in the bypass condition, thus preventing inadvertent actuation.
Through the semiautomatic tester, all possible logic combinations, with and without applicable permissives, are tested for each protection function.In addition, the master relay coil is pulse tested for continuity.
This verifies that the logic modules are that there is an intact voltage signal path to the master relay coils.ille Frequency of every 92 days on a STAGGERED TEST BASIS is justified in Referencer)n\'"'
A...SR 3.3.2.3 SR 3.3.2.3 is the performance of an ACTUATION LOGIC TEST as described in SR 3.3.2.2, except that the semiautomatic tester is not used and the continuity check does not have to be performed, as explained in the Note.This SR is applied to the balance of plant actuation logic and relays that do not have the SSPS test circuits installed to utilize the semiautomatic tester or perform the continuity che.cK, test is also performed every 31 days on a STAGGERED TEST BASIS.The Frequency is adequate based on industry operating experience, considering instrument reliability and operating history data., WOGSTS B 3.3.2-49 Rev.3.0, 03/31/04 Engineered Safety Feature Actuation System (ESFAS) Instrumentation - B 3.3.2 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.2.4 is the performance of a MASTER RELAY TEST.
The MASTER RELAY TEST is the energizing of the master relay, verifying contact operation and a low voltage continuity check of the slave relay coil. Upon master relay contact operation, a low voltage is injected to the lay, but - time -w-. Frequency of 92 days 1s justified ih Reference
: 9. fj- L SR 3.3.2.5 is the performance of a COT. A COT is performed on each required channel to ensure the entire channel will perform the intended Function. Setpoints must be found within the Allowable Values specified in Table 3.3.1-1. A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.
This clarifies what is an acceptable COT of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions. The difference between the current "as found" values and the previous test "as left" values must be consistent with the drift allowance used in the setpoint methodology.
The setpoint shall be left set consistent with the assumptions of the current unit specific setpoint methodology.
The "as found" and "as left" values must also be recorded and reviewed for consistency with the assumptions of Reference
: 6. he Frequency of 184 days is justified in Referenc WOG STS Rev. 3.0, 03/31/04 Engineered Safety Feature Actuation System (ESFAS)Instrumentation B 3.3.2 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.2.4 SR 3.3.2.4 is the performance of a MASTER RELAY TEST.The MASTER RELAY TEST is the energizing of the master relay, verifying contact operation and a low voltage continuity check of the slave relay coil.Upon master relay contact operation, a low voltage is injected to the slave relay coil.This voltage is insufficient to pick up the slave relay, but*
to demonstrate signal.path continuity.
hi.I
_.2 STAGGERED T BASl!f'The time allowed for the testing 4 hours)is justified in Reference 11 Frequency of 92 days IS justified in Reference 9&..)
SR 3.3.2.5 SR 3.3.2.5 is the performance of a COT.A COT is performed on each required channel to ensure the entire channel will perform the intended Function.Setpoints must be found within the Allowable Values specified in Table 3.3.1-1.A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable COT of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
The difference between the current"as found" values and the previous test"as left" values must be consistent with the drift allowance used in the setpoint methodology.
The setpoint shall be left set consistent with the assumptions of the current unit specific setpoint methodology.
The"as found" and"as left" values must also be recorded and reviewed for consistency with the assumptions of Reference 6.[!he Frequency of 184 days is justified in Reference 11t;.(Irl5e rt 2_WOGSTS B 3.3.2-50 Rev.3.0, 03/31/04 Engineered Safety Feature Actuation System (ESFAS) Instrumentation B 3.3.2 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.2.6 is the performance of a SLAVE RELAY TEST. The SLAVE RELAY TEST is the energizing of the slave relays. Contact operation is verified in one of two ways. Actuation equipment that may be operated in the design mitigation MODE is either allowed to function, or is placed in a condition where the relay contact operation can be verified without operation of the equipment. Actuation equipment that may not be operated in the design mitigation MODE is prevented from operation by the SLAVE RELAY TEST circuit. For this latter case, contact operation is ontaining the slave relay. based on industry and operating SR 3.3.2.7 SR 3.3.2.7 is the performance of a TADOT&e$ M318avs) This test is a check of the Loss of Offsite Power, Undervoltage RCP, and AFW Pump Suction Transfer on Suction Pressure - Low Functions. Each Function is tested up to, and including, the master transfer relay coils.
A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable TADOT of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
The test also includes trip devices that provide actuation signals directly to the SSPS. The SR is modified by a Note that excludes verification of setpoints for relays. Relay and are verified during CHANNEL
 
adequate. It is based on industry operating instrument reliability and operating history data.
WOG STS Rev. 3.0, 03/31/04 Engineered Safety Feature Actuation System (ESFAS)Instrumentation B 3.3.2 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.2.6 SR 3.3.2.6 is the performance of a SLAVE RELAY TEST.The SLAVE RELAY TEST is the energizing of the slave relays.Contact operation is verified in one of two ways.Actuation equipment that may be operated in the design mitigation MODE is either allowed to function, or is placed in a condition where the relay contact operation can be verified without operation of the equipment.
Actuation equipment that may not be operated inthedesign mitigation MODE is prevented from operation by the SLAVE RELAY TEST circuit.For this latter case, contact operation is verifiedba the slav.e..relay..IS perf ever[9'is.The FrequencYI'is...a.cte.quate",..-based on in ustry opera Ing experience., considering
..
and operating history data.():.nSeID_.SR 3.3.2.7 SR 3.3.2.7 is the performance of a TADOT@tew U!J2]fjaySJ This test is a check of the Loss of Offsite Power, Undervoltage RCP, and AFW Pump Suction Transfer on Suction Pressure-Low Functions.
Each Function is tested up to, and including, the master transfer relay coils.A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable TADOT of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
The test also includes trip devices that provide actuation signals directly to the SSPS.The SR is modified by a Note that excludes verification of setpoints for relays.Relay setpoints require elaborjlle bench calibration and are verified during CHANNEL CALIBRATION.l1he Frequencyk.
adequate.It is based on industry operating experience, J......_instrument reliability and operating history
.q?-(J:Vlserf 3".WOG STS B 3.3.2-51 Rev.3.0, 03/31/04 Engineered Safety Feature Actuation System (ESFAS) Instrumentation B 3.3.2 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.2.8 is the performance of a TADOT. This test is a check of the Manual start on trip of all MFW pumps. Each Manual Actuation Function is tested up to, and including, the master relay coils. A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable TADOT of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
In some instances, the test includes actuation of the end device (i.e., pump starts, valve cycles, etc.). me Frequenc based on industry operating experience and is consistent refueling cycle3The SR is modified by a Note that excludes verification of MY.---._* - -". setpoints during the TADOT for manual initiation Functions. The manual initiation Functions have no associated setpoints.
czfZ33- rrxm SR 3.3.2.9 is the performance of a CHANNEL CALIBRATION. - 'a r* -* - uu *-*-*"yU **.u*. .Uq*n"lY**--*.~-
a*..-d /i; CHAN performed
&JA.FE!W~~
&p&,"~k~~g.f~~i~~~
CALIBRATION is a complete check of the instrument loop, including the sensor.
The test verifies that the channel responds to measured parameter within the necessary range and accuracy. CHANNEL CALIBRATIONS must be performed consistent with the assumptions of the unit specific setpoint methodology. The difference between the current "as found" values and the previous test "as left" values must be consistent with the drift allowance used in the setpoint methodology.
Ehhe Frequency of
[18] months is based on the assumption of an [18] month calibration interval in the determination of the magnitude of equipment drift in the setpoint methodology.
wn~ert 3 This SR is modified by a Note stating that this test should include verification that the time constants are adjusted to the prescribed values where applicable.
WOG STS 6 3.3.2-52 Rev. 3.0, 03/31/04 Engineered Safety Feature Actuation System (ESFAS)Instrumentation B 3.3.2 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.2.8 SR 3.3.2.8 is the performance of a TADOT.This test is a check of the Manual A_cllJ.&sect;ill2!:'f!-.!.Qctions and W ump start on trip of all MFW pumps.fi rmedev 8 Each Manual Actuation Function is tested up to, and including, the master relay coils.A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable TADOT of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
In some instances, the test includes actuation of the end device (i.e., pump starts, valve cycles, etc.).ITlie Frequenc's adequate,.1....7\based on industry operating experience and is consistent witte yplca
......
SR is modified by a Note that excludes verification of setpoints during the TADOT for manual initiation Functions.
The manual initiation Functions have no associated setpoints.
..,--....SR 3.3.2.9 SR 3.3.2.9 is the performance of a CHANNEL CALIBRATION.
r;CHAN a,matelat CAll BRA TION is a complete check of the instrument loop, including the sensor.The test verifies that the channel responds to measured parameter within the necessary range and accuracy.CHANNEL CALIBRATIONS must be performed consistent with the assumptions of the unit specific setpoint methodology.
The difference between the current"as found" values and the previous test"as left" values must be consistent with the drift allowance used in the setpoint methodology.
-IThe Frequency of[18]months is based on the assumption of an[18]month calibration interval in the determination of the magnitude of equipment drift in the setpoint methodology.
This SR is modified by a Note stating that this test should include verification that the time constants are adjusted to the prescribed values where applicable.
WOGSTS B 3.3.2-52 Rev.3.0, 03/31/04 Engineered Safety Feature Actuation System (ESFAS) Instrumentation B 3.3.2 BASES SURVEILLANCE REQUIREMENTS (continued) WCAP-14036-P, Revision 1, "Elimination of Periodic Protection Channel Response Time Tests," (Ref.
: 14) provides the basis and methodology for using allocated signal processing and actuation logic response times in the overall verification of the protection system channel response time. The allocations for sensor, signal conditioning, and actuation logic response times must be verified prior to placing the component in operational service and re-verified following maintenance that may adversely affect response time.
In general, electrical repair work does not impact response time provided the parts used for repair are of the same type and value. Specific components identified in the WCAP may be replaced without verification testing. One example where response time could be affected is replacing the sensing assembly of a transmitter.
GSF RESPONSE TIME tests are conducted on an 1181 month STAGGERED TEST BASIS. Testing of the final actuation devices, which make up the bulk of the response time, is included in the testing of each channel. The final actuation device in one train is tested with each channel. Therefore, staggered testing results in response time verification of these devices every
[I 81 months. The
[I 81 month Frequency is consistent with the typical refueling cycle and is based on unit operating experience, which shows that random failures of instrumentation comoonents causina serious resoonse time dearadation.
., but not channel fail&, are infrequent occurrences.
This SR is modified by a Note that clarifies that the turbine driven AFW pump is tested within 24 hours after reaching [I0001 psig in the SGs. SR 3.3.2.1 1 is the performance of a TADOT as described in SR 3.3.2.8, except that it is performed for the P-4 Reactor Trip Interlock, and the Frequency is once per RTB cycle.
A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.
This clarifies what is an acceptable TADOT of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions. This Frequency is based on operating experience demonstrating that undetected failure of the P-4 interlock sometimes occurs when the RTB is cycled.
The SR is modified by a Note that excludes verification of setpoints during the TADOT. The Function tested has no associated setpoint. WOG STS B 3.3.2-54 Rev. 3.0, 03/31/04 EngineeredSafety Feature Actuation System (ESFAS)Instrumentation B 3.3.2 BASES SURVEILLANCE REQUIREMENTS (continued)
WCAP-14036-P, Revision 1,"Elimination of Periodic Protection Channel Response Time Tests," (Ref.14)provides the basis and methodology for using allocated signal processing and actuation logic response times in the overall verification of the protection system channel response time.The allocations for sensor, signal conditioning, and actuation logic response times must be verified prior to placing the component in operational service and re-verified following maintenance that may adversely affect response time.In general, electrical repair work does not impact response time provided the parts used for repair are of the same type and value.Specific components identified in the WCAP may be replaced without verification testing.One example where response time could be affected is replacing the sensing assembly of a transmitter.
GSF RESPONSE TIME tests are conducted on an[18)month STAGGERED TEST BASIS.Testing of the final actuation devices, which make up the bulk of the response time, is included in the testing of each channel.The final actuation device in one train is tested with each channel.Therefore, staggered testing results in response time verification of these devices every[18]months.The[18]month Frequency is consistent with the typical refueling cycle and is based on unit operating experience, which shows that random failures of instrumentation components causing serious response time degradation, but not channel failure, are infrequent occurrences. i'tID This SR is modified by a Note that clarifies that the turbine driven AFW pump is tested within 24 hours after reaching[1000]psig in the SGs.SR 3.3.2.11 SR 3.3.2.11 is the performance of a TADOT as described in SR 3.3.2.8, except that it is performed for the P-4 Reactor Trip Interlock, and the Frequency is once per RTB cycle.A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable TADOT of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
This Frequency is based onoperatingexperience demonstrating that undetected failure of the P-4 interlock sometimes occurs when the RTB is cycled.The SR is modified by a Note that excludes verification of setpoints during the TADOT.The Function tested has no associated setpoint.WOG STS B 3.3.2-54 Rev.3.0, 03/31/04 PAM Instrumentation B 3.3.3 BASES ACTIONS (continued)
E.l and E.2 If the Required Action and associated Completion Time of Condition C is not met and Table 3.3.3-1 directs entry into Condition E, the unit must be brought to a MODE where the requirements of this LC0 do not apply.
To achieve this status, the unit must be brought to at least MODE 3 within 6 hours and MODE 4 within 12 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required unit conditions from full power conditions in an orderly manner and without challenging unit systems.
At this unit, alternate means of monitoring Reactor Vessel Water Level and Containment Area Radiation have been developed and tested. These alternate means may be temporarily installed if the normal PAM channel cannot be restored to OPERABLE status within the allotted time. If these alternate means are used, the Required Action is not to shut down the unit but rather to follow the directions of Specification 5.6.5, in the Administrative Controls section of the TS. The report provided to the NRC should discuss the alternate means used, describe the degree to which the alternate means are equivalent to the installed PAM channels, justify the areas in which they are not equivalent, and provide a schedule for restoring the normal PAM channels.
SURVEILLANCE A Note has been added to the SR Table to clarify that SR 3.3.3.1 and REQUIREMENTS SR 3.3.3.3 apply to each PAM instrumentation Function in Table 3.3.3-1. L Performance of the CHANNEL CHECK&~~;~~FJG~~~
way3 ensures that a gross instrumentation failure has not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the two instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more seridus. A CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
The high radiation instrumentation should be compared to similar unit instruments located throughout the unit. WOG STS Rev. 3.1, 12/01/05 PAM Instrumentation B 3.3.3 BASES ACTIONS (continued)
E.1 and E.2 If the Required Action and associated Completion Time of Condition C is not met and Table 3.3.3-1 directs entry into Condition E, the unit must be brought to a MODE where the requirements of this LCO do not apply.To achieve this status, the unit must be brought to at least MODE 3 within 6 hours and MODE 4 within 12 hours.The allowed Completion Times are reasonable, based on operating experience, to reach the required unit conditions from full power conditions in an orderly manner and without challenging unit systems.At this unit, alternate means of monitoring Reactor Vessel Water Level and Containment Area Radiation have been developed and tested.These alternate means may be temporarily installed if the normal PAM channel cannot be restored to OPERABLE status within the allotted time.If these alternate means are used, the Required Action is not to shut down the unit but rather to follow the directions of Specification 5.6.5, in the Administrative Controls section of the TS.The report provided to the NRC should discuss the alternate means used, describe the degree to which the alternate means are equivalent to the installed PAM channels, justify the areas in which they are not equivalent, and provide a schedule for restoring the normal PAM channels.SURVEILLANCE REQUIREMENTS A Note has been added to the SR Table to clarify that SR 3.3.3.1 and SR 3.3.3.3 apply to each PAM instrumentation Function in Table 3.3.3-1.SR 3.3.3.1 Performance of the CHANNEL ensures that a gross instrumentation failure has not occurred.A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels.It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value.Significant deviations between the two instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more serio'us.A CHANNEL CHECK will detect gross channel failure;thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
The high radiation instrumentation should be compared to similar unit instruments located throughout the unit.WOG STS B 3.3.3-13 Rev.3.1,12/01/05 PAM Instrumentation B 3.3.3 BASES SURVEILLANCE REQUIREMENTS (continued) Agreement criteria are determined by the unit staff, based on a combination of the channel instrument uncertainties, including isolation, indication, and readability.
If a channel is outside the criteria, it may be an indication that the sensor or the signal processing equipment has drifted outside its limit. If the channels are within the criteria, it is an indication that the channels are OPERABLE.
As specified in the SR, a CHANNEL CHECK is only required for those channels that are normally energized.
Ehe Frequency of 31 days is based on operating experience that demonstrates that channel failure is rare. The CHANNEL CHECK supplements less formal, but more frequent, checks of channels during normal operational use of the displays associated with the LC0 required channels.
1181 montdor2 is a complete check of the instrument loop, including the sensor.
The test verifies that the channel responds to measured parameter with the necessary range and accuracy. This SR is modified by a Note that excludes neutron detectors.
The calibration method for neutron detectors is specified in the Bases of LC0 3.3.1, "Reactor Trip System (RTS)
Instrumentation." whenever a sensing element is replaced, the next required CHANNEL CALIBRATION of the Core Exit thermocouple sensors is accomplished by an inplace cross calibration that compares REFERENCES
[ 1. Unit specific document (e.g., FSAR, NRC Regulatory Guide 1.97 SER letter). J 2. Regulatory Guide 1.97, [date]. 3. NUREG-0737, Supplement I, "TMI Action Items." WOG STS Rev. 3.1, 12/01/05 PAM Instrumentation B 3.3.3 BASES SURVEILLANCE REQUIREMENTS (continued)
Agreement criteria are determined by the unit staff, based on a combination of the channel instrument uncertainties, including isolation, indication, and readability.
If a channel is outside the criteria, it may be an indication that the sensor or the signal processing equipment has drifted outside its limit.If the channels are within the criteria, it is an indication that the channels are OPERABLE.As specified in the SR, a CHANNEL CHECK is only required for those channels that are normally energized.
Uhe Frequency of 31 days is based on operating experience that demonstrates that channel failure is rare.The CHANNEL CHECK supplements less formal, but more frequent, checks of channels during normal operational use of the displays associated with the LCO required channels.
SR 3.3.3.2 A CHA.Lc'ALiBRATlgxf;"pert;,:-m;;.ever 18 mont or a ximately at
.CHANNEL CALIBRATION is a comp ete check of the instrument loop, including the sensor.The test verifies that the channel responds to measured parameter with the necessary range and accuracy.This SR is modified by a Note that excludes neutron detectors.
The calibration method for neutron detectors is specified in the Bases of LCO 3.3.1,"Reactor Trip System (RTS)Instrumentation." Whenever a sensing element is replaced, the next required CHANNEL CALIBRATION of the Core Exit thermocouple sensors is accomplished by an inplace cross calibration that compares the other sensing elements with the recently installed sensing element The Frequenc is based on operating ex rience an consistency with refueling cycle.."\Se.r'k REFERENCES
[1.Unit specific document (e.g., FSAR, NRC Regulatory Guide 1.97 SER letter).J 2.Regulatory Guide 1.97,[date].3.NUREG-0737, Supplement 1,"TMI Action Items." WOGSTS B 3.3.3-14 Rev.3.1,12/01/05 Remote Shutdown System B 3.3.4 BASES ACTIONS A Remote Shutdown System division is inoperable when each function is not accomplished by at least one designated Remote Shutdown System channel that satisfies the OPERABILITY criteria for the channel's Function. These criteria are outlined in the LC0 section of the Bases. A Note has been added to the ACTIONS to clarify the application of Completion Time rules. Separate Condition entry is allowed for each Function.
The Completion Time(s) of the inoperable channel(s)/train(s) of a Function will be tracked separately for each Function starting from the time the Condition was entered for that Function. Condition A addresses the situation where one or more required Functions of the Remote Shutdown System are inoperable. This includes the control and transfer switches for any required Function. The Required Action is to restore the required Function to OPERABLE status within 30 days. The Completion Time is based on operating experience and the low probability of an event that would require evacuat'on of the control room. I B.l and 8.2 If the Required Action and associated Completion Time of Condition A is not met, the unit must be brought to a MODE in which the LC0 does not apply. To achieve this status, the unit must be brought to at least MODE 3 within 6 hours and to MODE 4 within 12 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required unit conditions from full power conditions in an orderly manner and without challenging unit systems. SURVEILLANCE SR 3.3.4.1 REQUIREMENTS Performance of the CHANNEL CHECK@^^&?^
$6ay$ensures that a gross failure of instrumentation has not occurred.
A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the two instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more serious. CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying that the instrumentation continues to operate properly between each CHANNEL CALIBRATION. WOG STS B 3.3.4-3 Rev. 3.0, 03/31/04 BASES SURVEILLANCE REQUIREMENTS Remote Shutdown System B 3.3.4 ACTIONS A Remote Shutdown System division is inoperable when each function is not accomplished by at least one designated Remote Shutdown System channel that satisfies the OPERABILITY criteria for the channel's Function.These criteria are outlined in the LCO section of the Bases.A Note has been added to the ACTIONS to clarify the application of Completion Time rules.Separate Condition entry is allowed for each Function.The Completion Time(s)of the inoperable channel(s)/train(s) of a Function will be tracked separately for each Function starting from the time the Condition was entered for that Function.Condition A addresses the situation where one or more required Functions of the Remote Shutdown System are inoperable.
This includes the control and transfer switches for any required Function.The Required Action is to restore the required Function to OPERABLE status within 30 days.The Completion Time is based on operating experience and the low probability of an event that would require of the control room.B.1 and B.2 If the Required Action and associated Completion Time of Condition A is not met, the unit must be brought to a MODE in which the LCO does not apply.To achieve this status.the unit must be brought to at least MODE 3 within 6 hours and to MODE 4 within 12 hours.The allowed Completion Times are reasonable, based on operating experience.
to reach the required unit conditions from full power conditions in an orderly manner and without challenging unit systems.SR 3.3.4.1 Performance of the CHANNEL ensures that a gross failure of instrumentation has not occurred.A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels.It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value.Significant deviations between the two instrument channels could be an indication of excessive instrument drift in one of the channels or of somethingevenmore serious.CHANNEL CHECK will detect gross channel failure;thus, it is key to verifying that the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
-WOG STS B 3.3.4-3 Rev.3.0.03/31/04 Remote Shutdown System B 3.3.4 BASES SURVEILLANCE REQUIREMENTS (continued) Agreement criteria are determined by the unit staff, based on a combination of the channel instrument uncertainties, including indication and readability.
If the channels are within the criteria, it is an indication that the channels are OPERABLE. If a channel is outside the criteria, it may be an indication that the sensor or the signal processing equipment has drifted outside its limit.
As specified in the Surveillance, a CHANNEL CHECK is only required for those channels which are normally energized.
Ehe Frequency of 31 days is based upon operating experience which demonstrates that channel failure is rare.
The CHANNEL CHECK supplements less formal, but more frequent, checks of channels during normal operational use of the di with the LC0 required channels.
++ m-av -,-~-- SR 3.3.4.2 verifies each required Remote Shutdown System control circuit and transfer switch performs the intended function.
This verification is performed from the remote shutdown panel and locally, as appropriate. Operation of the equipment from the remote shutdown panel is not necessary.
The Surveillance can be satisfied by performance of a continuity check. This will ensure that if the control room becomes inaccessible, the unit can be placed and maintained in ODE 3 from the remote shutdown panel and the local control stations.
I! The [I81 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power. (However, this Surveillance is not required to be performed only during a unit outage.) Operating experience demonstrates that remote shutdown control channels usually pass the Surveillance test when performed at the
[I81 month Frequency.
4 ~.,n_rmu~w-rr*-r**u*c WOG STS B 3.3.4-4 Rev. 3.0, 03/31/04 Remote Shutdown System B 3.3.4 BASES SURVEILLANCE REQUIREMENTS (continued)
Agreement criteria are determined by the unit staff, based on a combination of the channel instrument uncertainties, including indication and readability.
If the channels are within the criteria, it is an indication that the channels are OPERABLE.If a channel is outside the criteria, it may be an indication that the sensor or the signal processing equipment has drifted outside its limit.As specified in the Surveillance, a CHANNEL CHECK is only required for those channels which are normally energized.
Uhe Frequency of 31 days is based upon operating experience which demonstrates that channel failure is rare.The CHANNEL CHECK supplements less formal, but more frequent, checks of channels during normal operational use of the dis la s assoc'with the LCO required channels...""",_..._'-..
SR 3.3.4.2 SR 3.3.4.2 verifies each required Remote Shutdown System control circuit and transfer switch performs the intended function.This verification is performed from the remote shutdown panel and locally, as appropriate.
Operation of the equipment from the remote shutdown panel is not necessary.
The Surveillance can be satisfied by performance of a continuity check.This will ensure that if the control room becomes inaccessible, the unit can be placed and maintained inJt10DE 3 from the remote shutdown panel and the local control stations.LIhe[18J month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power.(However, this Surveillance is not required to be performed only during a unit outage.)Operating experience demonstrates that remote shutdown controlchannelsusually pass the Surveillance test when performed at the[18J month Frequency..'C WOGSTS B 3.3.4-4 Rev.3.0, 03/31/04 Remote Shutdown System B 3.3.4 BASES SURVEILLANCE REQUIREMENTS (continued)
CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor. The test verifies that the channel responds to a measured parameter within the necessary range and accuracy. Whenever a sensing element is replaced, the next required CHANNEL CALIBRATION of the resistance temperature detectors (RTD) sensors is accomplished by an inplace cross calibration that compares the other sensing elements with the recently installed sensing element. Ee Frequency of 1181 months is based upon operating experience and consistency with the typical industry refueling cycle.
+, SR 3.3.4.4 is the performance of a TADOT(&~~. This test should verify the OPERABILITY of the reactor trip breakers (RTBs) open and closed indication on the remote shutdown panel, by actuating the RTBs. A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable TADOT of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
fihe Frequency& based upon operating experience and consistency with the typical industry refueling outage. ] - REFERENCES
: 1. 10 CFR 50, Appendix A, GDC 19. (p-tsert n) WOG STS Rev. 3.0, 03/31/04 Remote Shutdown System B 3.3.4 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.4.3 CHANNEL CALIBRATION is a complete check of the instrument loop and the sensor.The test verifies that the channel responds to a measured parameter within the necessary range and accuracy.REFERENCES Whenever a sensing element is replaced, the next required CHANNEL CALIBRATION of the resistance temperature detectors (RTD)sensors is accomplished by an in place cross calibration that compares the other sensing elements with the recently installed sensing element.&sect;e Frequency of[18]months is based upon operating experience and consistency with the typical industry refueling cycle.?
[SR 3.3.4.4 SR 3.3.4.4 is the performance ofa This test should verify the OPERABILITY of the reactor trip breakers (RTBs)open and closed indication on the remote shutdown panel, by actuating the RTBs.A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable TADOT of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
CThe Fre uenc.based upon operating experience and consistency with the typical industry refueling outage.]1.10 CFR 50, Appendix A, GDC 19.WOGSTS B 3.3.4-5 Rev.3.0, 03/31/04 LOP DG Start Instrumentation B 3.3.5 BASES ACTIONS (continued) Condition C applies to each of the LOP DG start Functions when the Required Action and associated Completion Time for Condition A or B are not met. In these circumstances the Conditions specified in LC0 3.8.1, "AC Sources - Operating," or LC0 3.8.2, "AC Sources - Shutdown," for the DG made inoperable by failure of the LOP DG start instrumentation are required to be entered immediately.
The actions of those LCOs provide for adequate compensatory actions to assure unit safety.
SURVEILLANCE SR 3.3.5.1 REQUIREMENTS Performance of the CHANNEL CHECK-~~SU~~S that a gross failure of instrumentation has not occurred.
A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels.
It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the two instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more serious. A CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying that the instrumentation continues to operate properly between each CHANNEL CALIBRATION. Agreement criteria are determined by the unit staff, based on a combination of the channel instrument uncertainties, including indication and readability. If a channel is outside the criteria, it may be an indication that the sensor or the signal processing equipment has drifted outside its limit. ahe Frequencws based on operating experience that demonstrates channel failure is rare. The CHANNEL CHECK supplements less formal, but more frequent, checks of channels during normal operational use of the displays associated with the LC0 required channels.
d------ WOG STS B 3.3.5-5 Rev. 3.0, 03/31/04 LOP DG Start Instrumentation B 3.3.5 BASES ACTIONS (continued)
Condition C applies to each of the LOP DG start Functions when the Required Action and associated Completion Time for Condition A or Bare not met.In these circumstances the Conditions specified in LCO 3.8.1,"AC Sources-Operating," or LCO 3.8.2,"AC Sources-Shutdown," for the DG made inoperable by failure of the LOP DG start instrumentation are required to be entered immediately.
The actions of those LCOs provide for adequate compensatory actions to assure unit safety.SURVEILLANCE REQUIREMENTS SR 3.3.5.1 Performance of the CHANNEL CHECK@[ceiver{12 houwensures that a gross failure of instrumentation has not occurred.A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels.It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value.Significant deviations between the two instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more serious.A CHANNEL CHECK will detect gross channel failure;thus, it is key to verifying that the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
Agreement criteria are determined by the unit staff, based on a combination of the channel instrument uncertainties, inclUding indication and readability.
If a channel is outside the criteria, it may be an indication that the sensor or the signal processing equipment has drifted outside its limit.fihe based on operating experience that demonstrates cFiannel failure is rare.The CHANNEL CHECK supplements less formal, but more frequent, checks of channels during normal operational use of the displays associated with the LCO required J:nsert'L-----WOGSTS B 3.3.5-5 Rev.3.0, 03/31/04 LOP DG Start Instrumentation B 3.3.5 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.5.2 is the performance of a TADOT. A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable TADOT of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least owe ner refuelina i~terval with applicable extensions.
vrm lijkrfdmed drv 131 dd The test checks trir, devices that urovide 'cgcthion signais ;iremypassing the analog process conti01 . . equipment.-r or these tests, the relay trip setpoints are verified and adjusted as necessary.
rhe is based on the known reliability of the relays and controls redundancy available, and has been shown to be acceptable SR 3.3.5.3 SR 3.3.5.3 is the performance of a CHANNEL CALIBRATION. The setpoints, as well as the response to a loss of voltage and a degraded voltage test, shall include a single point verification that the trip occurs within the required time delay, as shown in Reference
: 1. (:,"F~~l~~~p-erformed@E
~matelv at everv elinu. - .- -FLJ complete cnecRTf rne;nstrument loop, including the sensor.
The test verifies that the channel responds to a measured parameter within the necessary range and accuracy.
*r @e Frequency of 118) months is based on operating experience and consistency with the typical industry refueling cycle and is justified by the assumption of an [18] month calibration interval in the determination of the magnitude of equipment drift in the Setpoint analysis.
REFERENCES
: 1. FSAR, Section [8.3]. 2. FSAR, Chapter [I 51. 3. Plant specific setpoint methodology study.
WOG STS Rev. 3.0, 03/31/04 LOP DG Start Instrumentation B 3.3.5 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.5.2 SR 3.3.5.2 is the performance of a TADOT.A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable TADOT of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least o er refuelin'al with applicable extensions.
tirleOi1S
)pe med ry[31d.The test checks trip devices that provide actuation Signa s Irect y, bypassing the analog process control equipment.
For these tests, the relay trip setpoints are verified and adjusted as necessary.(fhe Frequenc is based on the known reliability of the relays and controls and the ultichannel redundancy available, and has been shown to be acceptable hrough operating experience.U)GJ 31 It,se.r Z SR 3.3.5.3 SR 3.3.5.3 is the performance of a CHANNEL CALIBRATION.
REFERENCES The setpoints, as well as the response to a loss of voltage and a degraded voltage test, shall include a single point verification that the trip occurs within the required time delay, as shown in Reference 1.A a
at every..refCJe1ing.j'CHANNEL CALIBRA IS a campeecce Instrument loop, including the sensor.The test verifies that the channel responds to a measured parameter within the necessary range and accuracy.""[lhe Frequency of[18J months is based on operating experience and consistency with the typical industry refueling cycle and is justified by the assumption of an[18]month calibration interval in the determination of the magnitude of equipment drift in the setpoint analysis.1.FSAR, Section[8.3J.2.FSAR, Chapter[15J.3.Plant specific setpoint methodology study.WOG STS B 3.3.5-6 Rev.3.0, 03/31/04 Containment Purge and Exhaust Isolation Instrumentation B 3.3.6 BASES SURVEILLANCE REQUIREMENTS (continued)
Performance of the CHANNEL CHECK a gross failure of instrumentation has n is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels.
It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the two instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more serious. A CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION. Agreement criteria are determined by the unit staff, based on a combination of the channel instrument uncertainties, including indication and readability.
If a channel is outside the criteria, it may be an indication that the sensor or the signal processing equipment has drifted outside its limit. /# ----.--.--*.~"-
Ete Frequency* based on operating experience that demonstrates LO 3 ! channel failure IS rare. The CHANNEL CHECK supplements less formal.
but more frequent, checks of channels during normal operational use of the displays associated with the LC0 required channels.
+s=x= SR 3.3.6.2 is the performance of an ACTUATION LOGIC TEST. The train being tested is placed in the bypass condition, thus preventing inadvertent actuation. Through the semiautomatic tester, all possible logic combinations, with and without applicable permissives, are tested for each protection function.
In addition, the master relay coil is pulse tested for continuity. This verifies that the logic modules are OPERABLE and there is an intact voltage signal path to the master relay coils.Ehis test is performed every 31 days on a STAGGERED TEST BASIS.
The Surveillance interval is acceptable based on instrument reliability and industry operating experience.
+--G=D WOG STS B 3.3.6-6 Rev. 3.0, 03/31/04 Containment Purge and Exhaust Isolation Instrumentation B 3.3.6 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.6.1 Performance of the CHANNELensures that a gross failure of instrumentation has not occurred.NNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels.It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value.Significant deviations between the two instrument channels could be an indication of excessive instrument drift in one of the channels or of somethingevenmore serious.A CHANNEL CHECK will detect gross channel failure;thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
Agreement criteria are determined by the unit staff, based on a combination of the channel instrument uncertainties, including indication and readability.
If a channel is outside the criteria, it may be an indication that the sensor or the signal processing equipment has drifted outside its limit.........-r-------*
..
based on operating experience that demonstrates (Ot 12 r"Y}Qr::::ttJ.:l
..("..c anne al ure IS rare.The CHANNEL CHECK supplements less formal, but more frequent, checks of channels during normal operational use of the displays associated with the LCO required t 3)SR 3.3.6.2 SR 3.3.6.2 is the performance of an ACTUATION LOGIC TEST.The train being tested is placed in the bypass condition, thus preventing inadvertent actuation.
Through the semiautomatic tester, all possible logic combinations, with and without applicable permissives, are tested for each protection function.In addition, the master relay coil is pulse tested for continuity.
This verifies that the logic modules are OPERABLE and there is an intact voltage signal path to the master relay coils.[!his test is performed every 31 days on a STAGGERED TEST BASIS.The Surveillance interval is acceptable based on instrument reliability and industry operating experience.WOGSTS B 3.3.6-6 Rev.3.0, 03/31/04 Containment Purge and Exhaust Isolation Instrumentation B 3.3.6 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.6.3 is the performance of a MASTER RELAY TEST. The MASTER RELAY TEST is the energizing of the master relay, verifying contact operation and a low voltage continuity check of the slave relay coil. Upon master relay contact operation, a low voltage is injected to the slave relay coil. This voltage is insufficient to pick up the slave relay, but large enough to demonstrate signal path continuity.
Ehis test is performed every 31 days on a STAGGERED TEST BASIS.
The Surveillance interval is acceptable based on instrument reliability and industry operating experience.
e- ~~r~set-t iL) SR 3.3.6.4 is the performance of an ACTUATION LOGIC TEST. The train being tested is placed in the bypass condition, thus preventing inadvertent actuation. Through the semiautomatic tester, all possible logic combinations, with and without applicable permissives, are tested for each protection function.
In addition, the master relay coil is pulse tested for continuity. This verifies that the logic modules are OPERABLE and there is an intact voltage signal path to the master relay coils. @is test is performed every 92 days on a STAGGERED TEST BASIS. The Surveillance interval is justified in Reference
: 2. 4 =nsert f) The SR is modified by a Note stating that the Surveillance is only applicable to the actuation logic of the ESFAS Instrumentation.
] SR 3.3.6.5 is the pIerformance of a MASTER RELAY TEST.
The MASTER RELAY TEST is the energizing of the master relay, verifying contact operation and a low voltage continuity check of the slave relay coil. Upon master relay contact operation, a low voltage is injected to the slave relay coil. This voltage is he slave relay, but large enough to demonstrate signal path performed every 92 days on a STAGGERED TEST BASIS. The Surveillance interval is justified in Reference
: 2. < G-rt, 2) The SR is modified by a Note stating that the Surveillance is only applicable to the master relays of the EFAS Instrumentation.
] WOG STS B 3.3.6-7 Rev. 3.0, 03/31/04 Containment Purge and EXhaust Isolation Instrumentation B 3.3.6 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.6.3 SR 3.3.6.3 is the performance of a MASTER RELAY TEST.The MASTER RELAY TEST is the energizing of the master relay, verifying contact operation and a low voltage continuity check of the slave relay coil.Upon master relay contact operation, a low voltage is injected to the slave relay coil.This voltage is insufficient to pick up the slave relay, but large enough to demonstrate signal path continuity.l!.his test is performed every 31 days on a STAGGERED TEST BASIS.The Surveillance interval is acceptable based on instrument reliability and industry operating experience.
<:-------a::
1.D TnSer1..2..[SR 3.3.6.4 SR 3.3.6.4 is the performance of an ACTUATION LOGIC TEST.The train being tested is placed in the bypass condition, thus preventing inadvertent actuation.
Through the semiautomatic tester, all possible logic combinations, with and without applicable permissives, are tested for each protection function.In addition, the master relay coil is pulse tested for continuity.
This verifies that the logic modules are OPERABLE and there is an intact voltage signal path to the master relay coils.lIb is test is performed every 92 days on a STAGGERED TEST BASIS.The Surveillance interval is justified in Reference 2.
3)The SR is modified by a Note stating that the Surveillance is only applicable to the actuation logic of the ESFAS Instrumentation.
][SR 3.3.6.5 SR 3.3.6.5 is the performance of a MASTER RELAY TEST.The MASTER RELAY TEST is the energizing of the master relay, verifying contact operation and a low voltage continuity check of the slave relay coil.Upon master relay contact operation, a low voltage is injected to the slave relay coil.This voltage is insufficient to pick uPrJhe slave relay, but large enough to demonstrate signal path continuity.
llhis test is performed every 92 days on a STAGGERED TEST Surveillance interval is justified in Reference 2.The SR is modified by a Note stating that the Surveillance is only applicable to the master relays of the EFAS Instrumentation.
]WOGSTS B 3.3.6-7 Rev.3.0, 03/31/04 Containment Purge and Exhaust Isolation Instrumentation B 3.3.6 BASES SURVEILLANCE REQUIREMENTS (continued) A COT is performe 9fdays$n each required channel to ensuri the entire channel orm the ~ntended  unction. A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable COT of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specificatio s tests at least once per refueling interval with applicable extensions.
$e Frequency is
,.re- -.wvlcu-.m based on the staff recommendation for increasing the availability of radiation monitors according to NUREG-1366 (Ref.
: 3) This test verifies the caiahty of Ke~ii'KEi%Ei-t~dF'*'lEc ntainment purge and exhaust system isolation. The setpoint shall be left consistent with the current unit specific calibration tolerance.
SR 3.3.6.7 is the performance of a SLAVE RELAY TEST. The SLAVE RELAY TEST is the energizing of the slave relays. Contact operation is verified in one of two ways. Actuation equipment that may be operated in the design mitigation mode is either allowed to function or is placed in a condition where the relay contact operation can be verified without operation of the equipment. Actuation equipment that may not be operated in the design mitigation mode is prevented from operation by the SLAVE RELAY TEST circuit. For this latter case, contact operation is verified -?-- by a continuity
+ *-. . check oft uit containing the slave relay.
Ftemerforrndd evd le bsd on instrument reliab SR 3.3.6.8 is the performance of a TADOT. This test is a check of the Manual Actuation
~unctions&d idrformtxk2Very 118f16onth,3.
Each Manual Actuation Function is tested up to, and including, the master relay coils. A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable TADOT of a relay. This is acceptable because all of the other required contacts of the relay are WOG STS B 3.3.6-8 Rev. 3.0, 03/31/04 Containment Purge and Exhaust Isolation Instrumentation B 3.3.6 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.6.6 A COT is 9tdayS)n each channel to ensure....the entire channel w,p;orm the Intended Function.A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable COT of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical tests at least once per refueling interval with applicable extensions.
f!tIe Frequency is based on the staff recommendation for increasing the availability of radiation monitors according to NUREG-1366 (Ref.3)!I"This test verifies the capability of Hie InsfrumenlafiorilOj5f6VTcrerneCOfitainment purge and exhaust system isolation.
The setpoint shall be left consistent with the current unit specific calibration procedure tolerance.
SR 3.3.6.7 SR 3.3.6.7 is the performance of a SLAVE RELAY TEST.The SLAVE RELAY TEST is the energizing of the slave relays.Contact operation is verified in one of two ways.Actuation equipment that may be operated in the design mitigation mode is either allowed to function or is placed in a condition where the relay contact operation can be verified without operation of the equipment.
Actuation equipment that may not be operated in the design mitigation mode is prevented from operation by the SLAVE RELAY TEST circuit.For this latter case, contact operation is verified by a contim.Jit check oft.cuit containing the slave relay.
The based on instrument reliability and SR 3.3.6.8 SR 3.3.6.8 is the performance of a TADOT.This test is a check of the Manual Actuation FunctionsWd is'iirformea--e\tery
[18I1'Ifci!Jtb).
Each Manual Actuation Function is tested up to, and including, the master relay coils.A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable TADOT of a relay.This is acceptable because all of the other required contacts of the relay are WOGSTS B 3.3.6-8 Rev.3.0, 03/31/04 Containment Purge and Exhaust Isolation Instrumentation B 3.3.6 BASES SURVEILLANCE REQUIREMENTS (continued) verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
In some instances, the test includes actuation of the end device (i.e., pump starts, valve cycles, etc.). The test also includes trip devices that provide actuation signals directly to the SSPS, bypassing the analog process control equipment. The SR is modified by a Note that excludes verification of setpoints during the TADOT. The Functions tested have no setpoints associated with them. based on the known reliability of the Function and the and has been shown to be acceptable through operating experience.
6--, nsert, 2.J SR 3.3.6.9 verifies that the channel responds to a measured parameter within the necessary range and accuracy.
6 18 W'io'I jj :g~he ~requen2s based on operating experience and is consistent with the typical industry refueling cycle.
1 REFERENCES I 10CFR100.11.
: 2. WCAP-15376, Rev. 0, October 2000.
: 3. NUREG-1366, [date]. WOG STS Rev. 3.0, 03/31/04 Containment Purge and Exhaust Isolation Instrumentation B 3.3.6 BASES SURVEILLANCE REQUIREMENTS (continued) verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
In some instances, the test includes actuation of the end device (Le., pump starts, valve cycles, etc.).The test also includes trip devices that provide actuation signals directly to the SSPS, bypassing the analog process control equipment.
The SR is modified by a Note that excludes verification of setpoints during the TADOT.The Functions tested have no setpoints associated with them.The FrequencYJs based on the known reliability of the Function and the e un ancyavailable, and has been shown to be acceptable through operating experience.
?-
1.10CFR100.11.
REFERENCES SR 3.3.6.9 A
.
[18]mol1lW(j0 at eve uelingfCHANNEL CALIBRATION is a c pee c ecae lOS rument loop, including the sensor.The test verifies that the channel responds to a measured parameter within the necessary range and accuracy.(QJ'18
{ihe based on operating experience and is consistent with the typical industry refueling cycle.2.WCAP-15376, Rev.0, October 2000.3.NUREG-1366,[date].WOG STS B 3.3.6-9 Rev.3.0, 03/31/04 CREFS Actuation Instrumentation B 3.3.7 BASES ACTIONS (continued)
C.l and C.2 Condition C applies when the Required Action and associated Completion Time for Condition A or B have not been met and the unit is in MODE 1, 2, 3, or 4. The unit must be brought to a MODE in which the LC0 requirements are not applicable. To achieve this status, the unit must be brought to MODE 3 within 6 hours and MODE 5 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required unit conditions from full power conditions in an orderly manner and without challenging unit systems. D.l - Condition D applies when the Required Action and associated Completion Time for Condition A or B have not been met when [recently] irradiated fuel assemblies are being moved. Movement of [recently] irradiated fuel assemblies must be suspended immediately to reduce the risk of acfidents that would require CREFS actuation. Condition E applies when the Required Action and associated Completion Time for Condition A or B have not been met in MODE 5 or 6. Actions must be initiated to restore the inoperable train(s) to OPERABLE status immediately to ensure adequate isolation capability in the event of a waste gas decay tank rupture. SURVEILLANCE A Note has been added to the SR Table to clarify that Table 3.3.7-1 REQUIREMENTS determines which SRs apply to which CREFS Actuation Functions. Performance of the CHANNEL
~~~~~G&G;-ensures that a gross failure of instrumentation has not occurred.
A CHANNEL CHECK is normally a comparison of the parameter indicated on me channel to a similar parameter on other channels.
It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the two instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more serious. A CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
WOG STS B 3.3.7-5 Rev. 3.0. 03/31/04 CREFS Actuation Instrumentation B 3.3.7 BASES ACTIONS (continued)
C.1 and C.2 Condition C applies when the Required Action and associated Completion Time for Condition A or B have not been met and the unit is in MODE 1, 2, 3, or 4.The unit must be brought to a MODE in which the LCO requirements are not applicable.
To achieve this status, the unit must be brought to MODE 3 within 6 hours and MODE 5 within 36 hours.The allowed Completion Times are reasonable, based on operating experience, to reach the required unit conditions from full power conditions in an orderly manner and without challenging unit systems.Condition D applies when the Required Action and associated Completion Time for Condition A or B have not been met when[recently]
irradiated fuel assemblies are being moved.Movement of[recently]
irradiated fuel assemblies must be suspended immediately to reduce the risk of actidents that would require CREFS actuation.
Condition E applies when the Required Action and associated Completion Time for Condition A or B have not been met in MODE 5 or 6.Actions must be initiated to restore the inoperable train(s)to OPERABLE status immediately to ensure adequate isolation capability in the event of a waste gas decay tank rupture.SURVEILLANCE REQUIREMENTS A Note has been added to the SR Table to clarify that Table 3.3.7-1 determineswhichSRs apply to which CREFS Actuation Functions.
SR 3.3.7.1 Performance of the CHANNEL that a gross failure of instrumentation has not occurred.A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels.It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value.Significant deviations between the two instrument channels could be an indication of excessive instrument drift in one of the channels or of somethingevenmore serious.A CHANNEL CHECK will detect gross channel failure;thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
WOGSTS B 3.3.7-5 Rev.3.0, 03/31/04 CREFS Actuation Instrumentation B 3.3.7 BASES SURVEILLANCE REQUIREMENTS (continued) Agreement criteria are determined by the unit staff, based on a combination of the channel instrument uncertainties, including indication and readability. If a channel is outside the criteria, it may be an indication that the sensor or the signal processing equipment has drifted outside its limit. s based on operating experience that demonstrates rare. The CHANNEL CHECK supplements less formal, but more freauent.
checks of channels during normal operational use of A COT is performed 66 n each required channel to ensure the entire channel will perform the intended function. This test verifies the capability of the instrumentation to provide the CREFS actuation. A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.
This clarifies what is an acceptable COT of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions. The setpoints shall left consistent with the unit specific calibration procedure tolerance. reliability of the acceptable through SR 3.3.7.3 is the performance of an ACTUATION LOGIC TEST. The train being tested is placed in the bypass condition, thus preventing inadvertent actuation. Through the semiautomatic tester, all possible logic combinations, with and without applicable permissives, are tested for each protection function.
In addition, the master relay coil is pulse tested for continuity. This verifies that the logic modules are OPE ABLE and there is an intact voltage signal path to the master relay coils.
? This test is performed every 31 days on a STAGGERED TEST BASIS. The Frequency is acceptable based on instrument reliability and industry operating experience.
WOG STS B 3.3.7-6 Rev. 3.0, 03/31/04 SR 3.3.7.3 CREFS Actuation Instrumentation B 3.3.7 BASES SURVEILLANCE REQUIREMENTS (continued)
Agreement criteria are determined by the unit staff, based on a combination of the channel instrument uncertainties, including indication and readability.
If a channel is outside the criteria, it may be an indication that the sensor or the signal processing equipment has drifted outside its limit.j:z..
based on operating experience that demonstrates failure is rare.The CHANNEL CHECK supplements less formal, but more frequent, checks of channels during normal operational use of the displays associated with the LCO required channels.,>--...
SR 3.3.7.2 A COT is performed enc;;&*;:v g211ays}m each required channel to ensure the entire channel will perform the intended function.This test verifies the capability of the instrumentation to provide the CREFS actuation.
A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable COT of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
The setpoints shallleft consistent with the unit specific calibration procedure tolerance.
me Frequency's based on the known reliability of the monitoring equipment and has been shown to be acceptable through operating experience'''''CE;'Se rC SR 3.3.7.3 is the performance of an ACTUATION LOGIC TEST.The train being tested is placed in the bypass condition, thus preventing inadvertent actuation.
Through the semiautomatic tester, all possible logic combinations, with and without applicable permissives, are tested for each protection function.In addition, the master relay coil is pulse tested for continuity.Thisverifies that the logic modules are and there is an intact voltage signal path to the master relay coils.[his test is performed every 31 days on a STAGGERED TEST BASIS.The Frequency is acceptable based on instrument reliability and industry operating experience.(E??)n5er WOGSTS B 3.3.7-6 Rev.3.0, 03/31/04 CREFS Actuation Instrumentation B 3.3.7 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.7.4 is the performance of a MASTER RELAY TEST. The MASTER RELAY TEST is the energizing of the master relay, verifying contact operation and a low voltage continuity check of the slave relay coil. Upon master relay contact operation, a low voltage is injected to the slave relay coil. This voltage is insufficient to pick u the slave relay, but large enough to demonstrate signal path continuity. This test is operating experience.
t performed every 31 days on a STAGGERED TEST SIS. The Frequency is acceptable based on instrument reliability and industry SR 3.3.7.5 is the performance of an ACTUATION LOGIC TEST.
The train being tested is placed in the bypass condition, thus preventing inadequate actuation. Through the semiautomatic tester, all possible logic combinations, with and without applicable permissives, are tested for each protection function.
In addition, the master relay coil is pulse tested for continuity.
This verifies that the logic modules are OPERABLE and there is an intact voltage signal path to the master relay coils.Ehis test is performed ever 92 days on a STAGGERED TEST BASIS.
The Surveillance interval is justified in Reference
: 1. -II=rtx) --*_-----*-
The SR is modified by a Note stating that the Surveillance is only applicable to the actuation logic of the ESFAS Instrumentation.
] SR 3.3.7.6 is the performance of a MASTER RELAY TEST. The MASTER RELAY TEST is the energizing of the master relay, verifying contact operation and a low voltage continuity check of the slave relay coil. Upon master relay contact operation, a low voltage is injected to the slave relay coil. This voltage is insufficient to pick up the slave relay, but large enough to demonstrate signal path continuity.
Ehis test is performed every 92 days on a STAGGERED TEST BASIS. The
~urveillance interval is justified in Reference 1.
The SR is modified by a Note stating that the Surveillance is only applicable to the master relays of the ESFAS Instrumentation.
] WOG STS 6 3.3.7-7 Rev. 3.0, 03/31/04 CREFS Actuation Instrumentation B 3.3.7 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.7.4 SR 3.3.7.4 is the performance of a MASTER RELAY TEST.The MASTER RELAY TEST is the energizing of the master relay, verifying contact operation and a low voltage continuity check of the slave relay coil.Upon master relay contact operation, a low voltage is injected to the slave relay coil.This voltage is insufficient to pick slave relay, but large enough to demonstrate signal path continuity.
This test is performed every 31 days on a STAGGERED TEST SIS.The Frequency is acceptable based on instrument reliability and industry operating experience.
{_(i.;\Ser t::i)[SR 3.3.7.5 SR 3.3.7.5 is the performance of an ACTUATION LOGIC TEST.The train being tested is placed in the bypass condition, thus preventing inadequate actuation.
Through the semiautomatic tester, all possible logic combinations, with and without applicable permissives, are tested for each protection function.In addition, the master relay coil is pulse tested for continuity.
This verifies that the logic modules are OPERABLE and there is an intact voltage signal path to the master relay coils.(1his test is performed ever 92 days on a STAGGERED TEST BASIS.The Surveillance interval is justified in Reference 1.I...L"'1 v'"\SerL,..,.-
--,._..,....
....
The SR is modified by a Note stating that the Surveillance is only applicable to the actuation logic of the ESFAS Instrumentation.
][SR 3.3.7.6 SR 3.3.7.6 is the performance of a MASTER RELAY TEST.The MASTER RELAY TEST is the energizing of the master relay, verifying contact operation and a low voltage continuity check of the slave relay coil.Upon master relay contact operation, a low voltage is injected to the slave relay coil.This voltage is insufficient to pick UP.the slave relay, but large enough to demonstrate signal path continuity.
/flJis test is performed every 92 days on a STAGGERED TEST BASIS.The Surveillance interval is justified in Reference 1.
t"2)The SR is modified by a Note stating that the Surveillance is only applicable to the master relays of the ESFAS Instrumentation.
]WOGSTS B 3.3.7-7 Rev.3.0, 03/31/04 CREFS Actuation Instrumentation B 3.3.7 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.7.7 SR 3.3.7.7 is the performance of a SLAVE RELAY TEST.
The SLAVE RELAY TEST is the energizing of the slave relays. Contact operation is verified in one of two ways. Actuation equipment that may be operated in the design mitigation MODE is either allowed to function or is placed in a condition where the relay contact operation can be verified without operation of the equipment. Actuation equipment that may not be operated in the design mitigation MODE is prevented from operation by the SLAVE RELAY TEST circuit.
For this latter case, contact operation is verified by a continuity check of the circuit containing the slave relay.
phis test is performed every
[92] days. The Frequency is acceptable based on instrument reliability and industry operating SR 3.3.7.8 is the ~erformance of a TADOT. This test is a check of the Manual ~ctuation' Functions@Ki"s~fi~~>. - .---- Each Manual Actuation Function is tested up to, and including, the master relay coils. A successful test of the required contact(s) of a channel relay may- be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable TADOT of a relay.
This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
In some instances, the test includes actuation of the end device (i.e., pump starts, valve cycles, etc.).
The test also includes trip devices that provide actuation signals directly J to the Solid State Protection System, bypassing the analog process 16 'f? iu 1 %control equipment.
Fe Frequency .s based on the known reliability of the
/ Function and the redundancy 4 aval able, and has been shown to be acceptable through operating experience.w~he SR is moditled by a Note ) that excludes verification of setpoints during the TADOT.
The Functions tested have no setpoints associated with them.
WOG STS B 3.3.7-8 Rev. 3.0, 03/31/04 CREFS Actuation Instrumentation B 3.3.7 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.7.7 SR 3.3.7.7 is the performance of a SLAVE RELAY TEST.The SLAVE RELAY TEST is the energizing of the slave relays.Contact operation is verified in one of two ways.Actuation equipment that may be operated in the design mitigation MODE is either allowed to function or is placed in a condition where the relay contact operation can be verified without operation of the equipment.
Actuation equipment that may not be operated inthedesign mitigation MODE is prevented from operation by the SLAVE RELAY TEST circuit.**
For this latter case, contact operation is verified by a continuity check of the circuit containing the slave relay.[Jhis test is performed every[92]days.The Frequency is acceptable based on instrument reliability and industry operating experience.
SR 3.3.7.8 SR 3.3.7.8 is the performance of a TADOT.This test is a check of the Manual Actuation Functions@E!iSperTOrii1'jq every;VaJ mOl)_tM.Each Manual Actuation Function is tested up to, and including, the master relay coils.A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable TADOT of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
In some instances, the test includes actuation of the end device (i.e., pump starts, valve cycles, etc.).The test also includes trip devices that provide actuation signals directly to the Solid State Protection System,bypassingthe analog process ls based on the known reliability of the Function andte re un ancy aval able, and has been shown to be.acceptable through operating experience.
The SR is mo I Ieya Note that excludes verification of setpoints during the TADOT.The Functions tested have no setpoints associated with them.(,.-I---t_It15er-2.WOGSTS B 3.3.7-8 Rev.3.0, 03/31/04 CREFS Actuation Instrumentation I3 3.3.7 BASES SURVEILLANCE REQUIREMENTS (continued) verifies that the channel responds to a measured parameter within the necessary range and accuracy. - and is consistent with WOG STS Rev. 3.0, 03131104 CREFS Actuation Instrumentation B 3.3.7 BASES SURVEILLANCE REQUIREMENTS (continued) 1.WCAP-15376, Rev.0, October 2000.REFERENCES SR 3.3.7.9 A a ximately at every r elin.HANNEL CALIBRATION is a compeec eck 0te instrument loop, including the sensor.The test verifies that the channel responds to a measured parameter within the necessary range and accuracy.
based on operating experience and is consistent with l-ffie typical industry refueling cycle.<&#xa3;--__WOGSTS B 3.3.7-9 Rev.3.0, 03/31/04 FBACS Actuation Instrumentation B 3.3.8 BASES ~ ACTIONS (continued)
Condition C applies when the Required Action and associated Completion Time for Condition A or B have not been met and [recently] irradiated fuel assemblies are being moved in the fuel building. Movement of [recently] irradiated fuel assemblies in the fuel building must be suspended immediately to eliminate the potential for events that could require FBACS actuation.
/ D.l and D.2 Condition D applies when the Required Action and associated Completion Time for Condition A or B have not been met and the unit is in MODE 1, 2, 3, or 4. The unit must be brought to a MODE in which the LC0 requirements are not applicable. To achieve this status, the unit must be brought to MODE 3 within 6 hours and MODE 5 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required unit conditions from full power conditions in an orderly manner and without challenging unit systems. SURVEILLANCE A Note has been added to the SR Table to clarify that table 3.3.8-1 REQUIREMENTS determines which SRs apply to which FBACS Actuation Functions.
Pelformance of the CHANNEL
~~~~~~ce/e~ou~nsuras that a gross failure of instrumentation has not occurred.
A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the two instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more serious. A CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
Agreement criteria are determined8by the unit staff, based on a combination of the channel instrument uncertainties, including indication and readability. If a channel is outside the criteria, it may be an indication that the sensor or the signal processing equipment has drifted outside its limit. WOG STS - - Rev. 3.0, 03/31/04 FBACS Actuation Instrumentation B 3.3.8 BASES ACTIONS (continued)
Condition C applies when the Required Action and associated Completion Time for Condition A or B have not been met and[recently]
irradiated fuel assemblies are being moved in the fuel building.Movement of[recently]
irradiated fuel assemblies in the fuel building must be suspended immediately to eliminate the potential for events that could require FBACS actuation.
D.1 and D.2 Condition D applies when the Required Action and associated Completion Time for Condition A or B have not been met and the unit is in MODE 1, 2, 3, or 4.The unit must be brought to a MODE in which the LCO requirements are not applicable.
To achieve this status, the unit must be brought to MODE 3 within 6 hours and MODE 5 within 36 hours.The allowed Completion Times are reasonable, based on operating experience, to reach the required unit conditions from full power conditions in an orderly manner and without challenging unit systems.SURVEILLANCE REQUIREMENTS A Note has been added to the SR Table to clarify that table 3.3.8-1 determineswhichSRs apply to which FBACS Actuation Functions.
SR 3.3.8.1 Performance of the CHANNEL that a gross failure of instrumentation has not occurred.A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels.It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value.Significant deviations between the two instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more serious.A CHANNEL CHECK will detect gross channel failure;thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
Agreement criteria are determined by the unit staff, based on a combination of the channel instrument uncertainties, including indication and readability.
If a channel is outside the criteria, it may be an indication that the sensor or the signal processing equipment has drifted outside its limit.WOGSTS B 3.3.8-5 Rev.3.0, 03/31/04 FBACS Actuation Instrumentation B 3.3.8 BASES SURVEILLANCE REQUIREMENTS (continued)
'9>+ *- ---* h- ~, ---I Ee ~re~uen;$s based on operating experience that demonstrates
<sj channel failure is rare. The CHANNEL CHECK supplements less formal, but more frequent, checks of channels during normal operational use of the displays associated with the LC0 required channels A COT is performed@ncefier)d~a~>n each required channel to ensure the entire channel will
~erform the intended function.
A successful test of the required contact(s) bf a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable COT of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions. This test verifies the capability of the instrumentation to provide the FBACS actuation.
The setpoints shall be left onsistent with the unit specific calibration procedure tolerance.6he Frequency of 92 days is based on the known reliability of the monitoring equipment and has been shown to be acceptable through operating experience.
=:;exa [ SR 3.3.8.3 is the ~erformance of an ACTUATION LOGIC TEST.
The -a2,9E lo$ ,. -- is tested .w,v.d every 31 days on 2s I AGGERED TE S&ASI$ All ~ossible loaic combinattons.
w~f~n~thout aaalicable
~ermisslves.
are'tested for Zach protection f'unction.~~&~~requ'eky is b&ed on the " known reliability of the relays and controls and the multichannel redundancy available, and has been shown to be acceptable through operating experience.
] @*T) SR 3.3.8.4 is the performance of a TADOT. This test is a che manual actuation function<and IS p@ormed/everv
[l Mmont manual actuation function is tested up to, and including, the master relay coils. A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable TADOT of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical WOG STS B 3.3.8-6 Rev. 3.0, 03/31/04 FBACS Actuation Instrumentation B 3.3.8 BASES SURVEILLANCE REQUIREMENTS (continued)
:-.....
based on operating experience that demonstrates
-.)..J:"f,;:,.,)
channel failure is rare.The CHANNEL CHECK supplements less formal, but more frequent, checks of channels during normal operational use of the displays associated with theLCO required
:[n..5 e ('1: jJ_,_V,_'""._
_..
SR 3.3.8.2 A COT is each required channel to ensure the entire Chan::, perform the intended function.A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable COT of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
This test verifies the capability of the instrumentation to provide the FBACS actuation.
The setpoints shall be with the unit specific calibration procedure tolerance.l!.he Frequency of 92 days is based on the known reliability of the monitoring equipment and has been shown to be acceptable through operating experience.
..L\se r t.7",)
.......,.,...-,.".
SR 3.3.8.3 SR 3.3.8.4 SR 3.3.8.4 is the performance of a TADOT.of the manual actuation function an IS p ormev1 month Each manual actuation function is tested up to, and including, the master relay coils.A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable TADOT of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical WOGSTS B 3.3.8-6 Rev.3.0, 03/31/04 FBACS Actuation Instrumentation B 3.3.8 BASES -- SURVEILLANCE REQUIREMENTS (continued) Specifications tests at least once per refueling interval with applicable extensions.
In some instances, the test includes actuation of the e nbi device (e.g.. pump starts, valve cycles, etc.). Ehe Frequency is based on operating experience and is consistent with the typical industry refueling c cle The SR is modified by a Note that excludes verification of setpo~nts during the TADOT. The Functions tested have no setpoints associated with them.
._-*.-.."-I------ (Ap;,CiLp is pep every~s~x3 oximatel at e refueling. HANNEL CALIBRATION IS a complete check of the instrumea loop, including the sensor. The test verifies that the channel responds to a measured parameter within the necessary range and accuracy.
Ehe Frequency is based on operating experience and is consistent with the typical industry refueling REFERENCES
: 1. 10CFR100.11.
: 2. Unit S~ecific Setaoint Calibration Procedure.
WOG STS Rev. 3.0, 03/31/04 FBACS Actuation Instrumentation B 3.3.8 BASES SURVEILLANCE REQUIREMENTS (continued)
Specifications tests at least once per refueling interval with applicable extensions.
In some instances, the test includes actuation of the end_device (e.g., pump starts, valve cycles, etc.).[he Frequency'Fs based on operating experience and is consistent with the typical industry refueling (}:r-The SR is modified by a Note that excludes verification of i Se.setpoints during the TADOr.The Functions tested have no setpoints associated with them.SR 3.3.8.5 complete check of the instrument loop, including the sensor.The test verifies that the channel responds to a measured parameter within the necessary range and accuracy.[Ihe Frequency is based on operating f--r:;'\experience and is consistent with the typical industry refueling REFERENCES 1.10 CFR 100.11.2.Unit Specific Setpoint Calibration Procedure.
WOG STS B 3.3.8-7 Rev.3.0, 03/31/04 BDPS B 3.3.9 BASES SURVEILLANCE SR 3.3.9.1 REQUIREMENTS The BDPS trains are subject to a COT and a CHANNEL CALIBRATION. - Performance of the CHANNEL ~~~~~~~er~~ours)ensures that gross failure of instrumentation has not occurred.
A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels.
It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the two instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more serious. A CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying that the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
Agreement criteria are determined by the unit staff based on a combination of the channel instrument uncertainties, including indication and readability.
If a channel is outside the criteria, it may be an indication that the senor or the signal processing equipment has drifted outside its E~he Frequenc 7- is based on operating experience that demonstrates channel failure is rare. The CHANNEL CHECK supplements less formal, but more frequent, checks of channels during normal operational use of the displays associated with the LC0 required channels.-
SR 3.3.9.2 SR 3.3.9.2 requires the performance of a ~0~6~~2IBgyb) to ensure that each train of the BDPS and associated trip setpoint are fully operational. A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable COT of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions. This test shall include verification that the boron dilution alarm setpoint is equal to or less than an increase of Mice the count rate within a 10 minute period. ahe Frequency of [92] days is consistent with the requirements for source range channels in WCAP-15376 (Ref.
21.9 WOE STS B 3.3.9-4 Rev. 3.0, 03/31/04 BDPS B 3.3.9 BASES SURVEILLANCE SR 3.3.9.1 REQUIREMENTS The BDPS trains are sUbject to a COT and a CHANNEL CALIBRATION.
Performance of the CHANNEL that gross failure of instrumentation has not occurred.A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels.It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value.Significant deviations between the two instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more serious.A CHANNEL CHECK will detect gross channel failure;thus, it is key to verifying that the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
Agreement criteria are determined by the unit staff based on a combination of the channel instrument uncertainties, including indication and readability.
If a channel is outside the criteria, it may be an indication that the senor or the signal processing equipment has drifted outside its limit.of I[The Frequenc IS based on operating experience that demonstrates channel failure is rare.The CHANNEL CHECK supplements less formal, but more frequent, checks of channels during normal operational use of the displays associated with the LCO required
__r.:!-VIse,..t.v SR 3.3.9.2 SR 3.3.92 requires the performance of a to ensure that each train of the BOPS and associated trip setpoint are fully operational.
A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable COT of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
This test shall include verification that the boron dilution alarm setpoint is equal to or less than an increase of twice the count rate within a 10 minute period.[fhe Frequency of[92]days is consistent with the requirements for source range channels in 15376 (Ref.2).II1 se",t;t WOGSTS B 3.3.9-4 Rev.3.0, 03/31/04 BDPS B 3.3.9 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.9.3 is the performance of a CHANNEL CALIBRATIO~ (mh>. CHANNEL CALIBRATION is a complete check of the instrument loop, including the sensor except the neutron detector of the SRM circuit. The test verifies that the channel responds to a measured parameter within the necessary range and accuracy.
For the BDPS, the CHANNEL CALIBRATION shall include verification that on a simulated or actual boron dilution flux doubling signal the centrifugal charging pump suction valves from the RWST open, and the normal CVCS volume control tank discharge valves close in the required closure time of 2 20 seconds. "* 6f I %pV2&'5 c The ~re~uenc~?s based on operating experience and consistency with the typical industry refueling cycle.& gn~ed~ ) REFERENCES
: 1. FSAR, Chapter
[I 51. 2. WCAP-15376, Revision 0, October 2000. WOG STS Rev. 3.0, 03131104 BOPS B 3.3.9 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.9.3 SR 3.3.9.3 is the performance of a CHANNELCHANNEL CALIBRATION is a complete check of the instrument loop, including the sensor except the neutron detector of the SRM circuit.The test verifies that the channel responds to a measured parameter within the necessary range and accuracy.For the BDPS, the CHANNEL CAL/BRA TION shall include verification that on a simulated or actual boron dilution flux doubling signal the centrifugal charging pump suction valves from the RWST open, and the normal cves volume control tank discharge valves close in the required closure time of S 20 seconds.,&->-/a)'Y];;-olh5J
[rhe based on operating experience and consistency with the typical industry refueling cycle.'I Yl$er+.:2 REFERENCES WOGSTS 1.FSAR, Chapter[15].2.WCAP-15376, Revision 0, October 2000.B 3.3.9-5 Rev.3.0,03/31/04 RCS Pressure, Temperature, and Flow DNB Limits B 3.4.1 BASES SURVEILLANCE SR 3.4.1 .I REQUIREMENTS r~ince Required Action A.l allows a Completion Time of 2 hours to restore parameters that are not within limits, the 12 hour Surveillance Frequency for pressurizer pressure is sufficient to ensure the pressure can be restored to a normal operation, steady state condition following load changes and other expected transient operations.
The 12 hour interval has been shown by operating practice to be sufficient to regularly assess for potential degradation and to verify operation is within safety analysis - - ^**.- . .. ..* 7'..-."u assumptions.
(--.,,..-
., ,".."." ..*.,.-. -. ,,.SW.." since Required Action A.l allows a Completion Time of 2 hours to restore parameters that are not within limits, the 12 hour Surveillance Frequency for RCS average temperature is sufficient to ensure the temperature can be restored to a normal operation, steady state condition following load changes and other expected transient operations. The 12 hour interval has been shown by operating practice to be sufficient to regularly assess for potential degradation and to verify operation is within safety analysis assumptions.
+-tiE-~~3 bhe 12 hour Surveillance Frequency for RCS total flow rate is performed using the installed flow instrumentation.
The 12 hour interval has been shown by operating practice to be sufficient to regularly assess potential degradation and to verify operation within safety analysis assumptions.
Measurement of RCS total flow rate by performance of a precision calorimetric heat balance@~~s)allows the installed RCS flow instrumentation to be calibrated and verifies the actual RCS flow rate is greater than or equal to the minimum required RCS flow rate.
Ehhe Frequency of [A 81 months reflects the importance of verifying flow after a refueling outage when the core has,been altered, which may have caused an alteration of flow resistance. ( @rrsert~-)
WOG STS B 3.4.1-4 Rev. 3.0, 03/31/04 BASES SURVEILLANCE REQUIREMENTS RCS Pressure, Temperature, and Flow DNB Limits B 3.4.1 SR 3.4.1.1[Since Required Action A.1 allows a Completion Time of 2 hours to restore parameters that are not within limits, the 12 hour Surveillance Frequency for pressurizer pressure is sufficient to ensure the pressure can be restored to a normal operation, steady state condition following load changes and other expected transient operations.
The 12 hour interval has been shown by operating practice to be sufficient to regularly assess for potential degradation and to verify operation is within safety analysis assumpt,'ons ,,''.',,,._-.."'-_.".,.'-L""',.I.'.I.,*r)...,;.;**."I,.*.::"l::D SR 3.4.1.2[Since Required Action A.1 allows a Completion Time of 2 hours to restore parameters that are not within limits, the 12 hour Surveillance Frequency for ReS average temperature is sufficient to ensure the temperature can be restored to a normal operation, steady state condition following load changes and other expected transient operations.
The 12 hour interval has been shown by operating practice to be sufficient to regularly assess for potential degradation and to verify operation is within safety analysis assumptions.__
SR 3.4.1.3[The 12 hour Surveillance Frequency for RCS total flow rate is performed using the installedflowinstrumentation.
The 12 hour interval has been shown by operating practice to be sufficient to regularly assess potential degradation and to verify operation within safety analysis assumptionSd&#xa3;;
&#xa3;._5e r 2)SR 3.4.1.4 Measurement of RCS total flow rate by performance of a precision calorimetric heat balance@e the installed RCS flow instrumentation to be calibrated and verifies the actual RCS flow rate is greater than or equal to the minimum required RCS flow rate.Uhe Frequency of[18]months reflects the importance of verifying flow after a refueling outage when the core has been altered, which may have caused an alteration of flow resistance,<
WOGSTS 83.4.1-4 Rev.3.0, 03/31/04 RCS Minimum Temperature for Criticality B 3.4.2 BASES SURVEILLANCE SR 3.4.2.1 REQUIREMENTS RCS loo avera e temper ture is required to be verified at or above (541)"F&~3
&e SR to verify RCS loop average temperatures every 12 hours takes into account indications and alarms that are continuously available to the operator in the control room and is consistent with other routine Surveillances which are typically performed once per shift. In addition, operators are trained to be sensitive to RCS temperature during approach to criticality and will ensure that the minimum temperature for criticality is met as criticality is approached.
REFERENCES
: 1. FSAR, Section
[15.0.3].
WOG STS Rev. 3.0, 03/31/04 BASES SURVEILLANCE REQUIREMENTS REFERENCES RCS Minimum Temperature for Criticality B 3.4.2 SR 3.4.2.1 RCS is required to be verified at or above[541]OF ver;y 12lhour&sect;)(Lhe SR to verify RCS loop average temperatures every 12 hours takes into account indications and alarms that are continuously available to the operator in the control room and is consistent with other routine Surveillances which are typically performed once per shift.In addition, operators are trained to be sensitive to ReS temperature during approach to criticality and will ensure that theminimum temperature for criticality is met as criticality is approached.
.j;se r 1.FSAR, Section[15.0.3J.WOG STS B 3.4.2-3 Rev.3.0, 03/31/04 RCS P/T Limits B 3.4.3 BASES -- ACTIONS (continued) Besides restoring operation within limits, an evaluation is required to determine if RCS operation can continue. The evaluation must verify that the RCPB integrity remains acceptable and must be completed prior to entry into MODE
: 4. Several methods may be used, including comparison with pre-analyzed transients in the stress analyses, or inspection of the components.
ASME Code, Section XI, Appendix E (Ref. 7), may be used to support the evaluation. However, its use is restricted to evaluation of the vessel beltline.
Condition C is modified by a Note requiring Required Action C.2 to be completed whenever the Condition is entered. The Note emphasizes the need to perform the evaluation of the effects of the excursion outside the allowable limits. Restoration alone per Required Action C.l is insufficient because higher than analyzed stresses may have occurred and may have affected the RCPB integrity.
SURVEILLANCE SR 3.4.3.1 REQUIREMENTS Verification that operation is within the PTLR limits is required@
mdwhen RCS pressure and temperature conditions are undergoing planned changes.ghi in view of the control room indicat Also, since temperature rate of ch deviations within a reasonable time.
increments, 30 minutes permits ass Surveillance for heatup, cooldown, when the definition given In the relevant plant procedure for ending the activity is satisfied.
This SR is modified by a Note that only requires this SR to be performed during system heatup, cooldown, and ISLH testing. No SR is given for criticality operations because LC0 3.4.2 contains a more restrictive requirement. - REFERENCES
: 1. WCAP-7924-A, April 1975. 2. 10 CFR 50, Appendix G. 3. ASME, Boiler and Pressure Vessel Code, Section Ill, Appendix G. WOG STS B 3.4.3-6 Rev. 3.0, 03/31/04 RCS PIT Limits B 3.4.3 BASES ACTIONS (continued)
Besides restoring operation within limits, an evaluation is required to determine if RCS operation can continue.The evaluation must verify that the RCPB integrity remains acceptable and must be completed prior to entry into MODE 4.Several methods may be used, including comparison with pre-analyzed transients in the stress analyses, or inspection of the components.
ASME Code, Section XI, Appendix E (Ref.7), may be used to support the evaluation.
However, its use is restricted to evaluation of the vessel beltline.Condition C is modified by a Note requiring Required Action C.2 to be completed whenever the Condition is entered.The Note emphasizes the need to perform the evaluation of the effects of the excursion outside the allowable limits.Restoration alone per Required Action C.1 is insufficient because higher than analyzed stresses may have occurred and may have affected the RCPB integrity.
SURVEILLANCE REQUIREMENTS REFERENCES SR 3.4.3.1 Verification that operation is within the PTLR limits is
.@IDinl6teS>when RCS pressure and temperature conditions are undergoing planned changes.[Jhis Frequency,js considered reasonable in view of the control room indication available to monitor ReS srarls.Also, since temperature rate of change limits are specified in hourly permits.assessment and correction for
.....;)deViations within a reasonable
,0I jQ Surveillance for heatup, cooldown, or fS[H testing may be discontinued when the definition given in the relevant plant procedure for ending the activity is satisfied.
This SR is modified by a Note that only requires this SR to be performed during system heatup, cooldown, and ISLH testing.No SR is given for criticality operations because LCO 3.4.2 contains a more restrictive requirement.
1.WCAP-7924-A, April 1975.2.10 CFR 50, Appendix G.3.ASME, Boiler and Pressure Vessel Code, Section III, Appendix G.WaG STS B 3.4.3-6 Rev.3.0, 03/31/04 RCS Loops - MODES 1 and 2 B 3.4.4 BASES APPLICABILITY (continued)
Operation in other MODES is covered by: LC0 3.4.5, "RCS Loops - MODE 3," LC0 3.4.6, "RCS Loops - MODE 4," LC0 3.4.7, "RCS Loops - MODE 5, Loops Filled," LC0 3.4.8, "RCS Loops - MODE 5, Loops Not Filled," LC0 3.9.5, "Residual Heat Removal (RHR) and Coolant Circulation - High Water Level" (MODE 6), and LC0 3.9.6, "Residual Heat Removal (RHR) and Coolant Circulation - Low Water Level" (MODE 6). ACTIONS If the requirements of the LC0 are not met, the Required Action is to reduce power and bring the plant to MODE 3. This lowers power level and thus reduces the core heat removal needs and minimizes the possibility of violating DNB limits. The Completion Time of 6 hours is reasonable, based on operating experience, to reach MODE 3 from full power conditions in an orderly manner and without challenging safety systems. SURVEILLANCE SR 3.4.4.4 REQUIREMENTS This SR requires verification~verdl7~hat each RCS loop is in operation. Verification includes flow rate, temperature, or pump status monitoring, which help ensure that forced flow is providing heat removal while maintaining the margin to DNB. Ehe Frequency of 12 hours is sufficient considering other indications and alarms available to the operator in the control room to monitor RCS loop performance.
6 . . J REFERENCES 1.
FSAR, Section [ 1. WOG STS Rev. 3.1, 12/01 I05 RCS LoopsMODES 1 and 2 B3.4.4 BASES APPLICABILITY (continued)
Operation in other MODES is covered by: LCO 3.4.5,"RCS Loops-MODE 3," LCO 3.4.6,"RCS Loops-MODE 4," LCO 3.4.7,"RCS Loops-MODE 5, Loops Filled," LCO 3.4.8,"RCS Loops-MODE 5, Loops Not Filled," LCO 3.9.5,"Residual Heat Removal (RHR)and Coolant Circulation*
High Water Level" (MODE 6), and LCO 3.9.6,"Residual Heat Removal (RHR)and Coolant CirculationLow Water Level" (MODE 6).ACTIONS If the requirements of the LCO are not met, the Required Action is to reduce power and bring the plant to MODE 3.This lowers power level and thus reduces the core heat removal needs and minimizes the possibility of violating DNB limits.The Completion Time of 6 hours is reasonable, based on operating experience, to reach MODE 3 from full power conditions in an orderly manner and without challenging safety systems.SURVEILLANCE REQUIREMENTS REFERENCES SR 3.4.4.1 This SR requires verificationceverl12 t<O!J[SAhat each RCS loop is in operation.
Verification includes flow rate, temperature, or pump status monitoring,whichhelp ensure that forced flow is providing heat removal while maintaining the margin to DNB.ffhe Frequency of 12 hours is sufficient considering other indications and alarms available to the operator in the control room to monitor RCS loop performance.
1.FSAR, Section[].WOGSTS B 3.4.4-3 Rev.3.1,12/01/05 RCS Loops - MODE 3 B 3.4.5 BASES - - . ACTIONS (continued)
D.l, D.2, and D.3 If [two] [required] RCS loops are inoperable or a required RCS loop is not in operation, except as during conditions permitted by the Note in the LC0 section, the Rod Control System must be placed in a condition incapable of rod withdrawal (e.g., all CRDMs must be de-energized by opening the RTBs or de-energizing the MG sets). All operations involving introduction of coolant into the RCS with boron concentration less than required to meet the minimum SDM of LC0 3.1.1 must be suspended, and action to restore one of the RCS loops to OPERABLE status and operation must be initiated. Boron dilution requires forced circulation for proper mixing, and opening the RTBs or de-energizing the MG sets removes the possibility of an inadvertent rod withdrawal. Suspending the introduction of coolant into the RCS of coolant with boron concentration less than required to meet the minimum SDM of LC0 3.1 .I is required to assure continued safe operation. With coolant added without forced circulation, unmixed coolant could be introduced to the core, however coolant added with boron concentration meeting the minimum SDM maintains acceptable margin to subcritical operations. The immediate Completion Time reflects the importance of maintaining operation for heat removal. The action to restore must be continued until one loop is restored to OPERABLE status and operation.
SURVEILLANCE SR 3.4.5.1 REQUIREMENTS
.-,- This SR requires verification -hat the required loops are in operation. Verification includes flow rate, temperature, and pump status monitoring, which help ensure that forced flow is providing heat removal.
fihe Frequency of 12 hours is sufficient considering other indications and alarms available to the o~erator in the control room to monitor RCS loot, performance.
&++flLF-;;-rs r1.J c". SR 3.4.5.2 requires verification of SG OPERABILITY. SG OPERABILITY is verified by ensuring that the secondary side narrow range water level is r [17]% for required RCS loops. If the SG secondary side narrow range water level is < [17]%, the tubes may become uncovered and the associated loop ma not be capable of providing the heat sink for removal of the decay heat.
the 12 hour Frequency is considered adequate in view of other indications available in the control room to alert the operator WOG STS -- Rev. 3.1, 12101105 RCS Loops-MODE 3 B 3.4.5 BASES ACTIONS (continued)0.1,0.2, and 0.3 If[two][required]
RCS loops are inoperable or a required RCS loop is not in operation, except as during conditions permitted by the Note in the LCO section, the Rod Control System must be placed in a condition incapable of rod withdrawal (e.g., all CROMs must be de-energized by opening the RTBs or de-energizing the MG sets).All operations involving introduction of coolant into the RCS with boron concentration less than required to meet the minimum SOM of LCO 3.1.1 must be suspended, and action to restore one of the RCS loops to OPERABLE status and operation must be initiated.
Boron dilution requires forced circulation for proper mixing, and opening the RTBs or de-energizing the MG sets removes the possibility of an inadvertent rod withdrawal.
Suspending the introduction of coolant into the RCS of coolant with boron concentration less than required to meet the minimum SOM of LCO 3.1.1 is required to assure continued safe operation.
With coolant added without forced circulation, unmixed coolant could be introduced to the core, however coolant addedwithboron concentration meeting the minimum SDM maintains acceptable margin to subcritical operations.
The immediate Completion Time reflects the importance of maintaining operation for heat removal.The action to restore must be continued until one loop is restored to OPERABLE status and operation.
SURVEILLANCE SR 3.4.5.1 REQUIREMENTS This SR requires verification 2!601JfSXhat the required loops are in.operation.
Verification includes flow rate, temperature, and pump status monitoring, which help ensure that forced flow is providing heat removal.[ihe Frequency of 12 hours is sufficient considering other indications and alarms available to the operator in the control room to monitor RCS loop performance.
r E:V-+/--n.;:Je.,__" SR 3.4.5.2 SR 3.4.5.2 requires verification of SG OPERABILITY.
SG OPERABILITY is verified by ensuring that the secondary side narrow range water level is[17]%for required ReS loops.If the SG secondary side narrow range water level is<[17]%, the tubes may become uncovered and the associated loopnot be capable of providing the heat sink for removal of the decay heat.\,Ihe 12 hour Frequency is considered adequate in view of other indications available in the control room to alert the operator to a loss of SG level.
.....-..'-T"';;)..
'.'.C:r: nr t.;;';;WOGSTS B 3.4.5-5 Rev.3.1,12/01/05 RCS Loops - MODE 3 B 3.4.5 BASES SURVEl LLANCE REQUIREMENTS (continued)
Verification that each required RCP is OPERABLE ensures that safety analyses limits are met. The requirement also ensures that an additional RCP can be placed in operation, if needed, to maintain decay heat removal and reactor coolant circulation. Verification is performed by verifying proper breaker alignment and power availability to each required RCP. Alternatively, verification that a pump is in operation also verifies proper breaker alignment and power availability.
6% *--...-, uw.--v- This SR is modified by a Note that states the SR is not required to be performed until 24 hours after a required pump is not in operation.
_? REFERENCES None. administrative controls available and has been shown to be I WOG STS Rev. 3.1, 12/01/05 Res Loops-MODE 3 B 3.4.5 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.4.5.3 Verification that each required RCP is OPERABLE ensures that safety analyses limits are met.The requirement also ensures that an additional Rep can be placed in operation, if needed, to maintain decay heat removal and reactor coolant circulation.
Verification is performed by verifying proper breaker alignment and power availability to each required RCP.Alternatively, verification that a pump is in operation also verifies proper breaker alignment and power availability....., 1I\'1..........
I......_This SR is modified by a Note that states the SR is not required to be performed until 24 hours after a required pump is not in operation.
REFERENCES None.[The Frequency of 7 days is considered reasonable in view of other adm inistrative controls available and has been shown to be acceptable by operating experience...--'"-----
IYlSerf;)........._.....-.......-_,-,.....,..-,---...-_--_
.....,._----_.. WOGSTS B 3.4.5-6 Rev.3.1,12/01/05 RCS Loops - MODE 4 6 3.4.6 BASES ACTIONS (continued)
B.l and B.2 If two required loops are inoperable or a required loop is not in operation, except during conditions permitted by Note 1 in the LC0 section, all operations involving introduction of coolant into the RCS with boron concentration less than required to meet the minimum SDM of LC0 3.1.1 must be suspended and action to restore one RCS or RHR loop to OPERABLE status and operation must be initiated. The required margin to criticality must not be reduced in this type of operation. Suspending the introduction of coolant into the RCS of coolant with boron concentration less than required to meet the minimum SDM of LC0 3.1.1 is required to assure continued safe operation.
With coolant added without forced circulation, unmixed coolant could be introduced to the core, however coolant added with boron concentration meeting the minimum SDM maintains acceptable margin to subcritical operations. The immediate Completion Times reflect the importance of maintaining operation for decay heat removal. The action to restore must be continued until one loop is restored to OPERABLE status and operation. SURVEILLANCE SR 3.4.6.1 REQUIREMENTS This SR requires verification
-=&that the required RCS or RHR loop is in operation. Verification includes flow rate, temperature, or pump status monitoring, which help ensure that forced flow is providing heat removal.
rhe Frequency of 12 hours is sufficient considering other indications and alarms available to the operator in the control room to monitor RCS and RHR loop performance.
SR 3.4.6.2 requires verification of SG OPERABILITY.
SG OPERABILITY is verified by ensuring that the secondary side narrow range water level is 2 [17]%. If the SG secondary side narrow range water level is
< [17]%, the tubes may become uncovered and the associated loop may not be apable of providing the heat sink necessary for removal of decay heat.
he 12 hour Frequency is considered adequate in view of other indications available in the control room to alert the operator to the loss of SG level. (T--'TT ZP .5&r WOG STS B 3.4.6-4 Rev. 3.1, 12101105 RCS Loops-MODE 4 B 3.4.6 BASES ACTIONS (continued)
B.1 and B.2 If two required loops are inoperable or a required loop is not in operation, except during conditions permitted by Note 1 in the LCO section, all operations involving introduction of coolant into the RCS with boron concentration less than required to meet the minimum SOM of lCO 3.1.1 must be suspended and action to restore one RCS or RHR loop to OPERABLE status and operation must be initiated.
The required margin to criticality must not be reduced in this type of operation.
Suspending the introduction of coolant into the ReS of coolant with boron concentration less than required to meet the minimum SOM of LCO 3.1.1 is required to assure continued safe operation.
With coolant added without forced circulation, unmixed coolant could be introduced to the core, however coolant added with boron concentration meeting the minimum SDM maintains acceptable margin to subcritical operations.
The immediate Completion Times reflect the importance of maintaining operation for decay heat removal.The action to restore must be continued until one loop is restored to OPERABLE status and operation.
SURVEILLANCE REQUIREMENTS SR 3.4.6.1 This SR requires verification
&sect;riiiThg,uci)that the required RCS or RHR loop is in operation.
Verification includes flow rate, temperature, or pump status monitoring, which help ensure that forced flow is providing heat removal.[he Frequency of 12 hours is sufficient considering other indications and alarms available to the operator in the control room to monitor RCS and RHR loop 1'-1""'" r:<:-1::>t" SR 3.4.6.2 SR 3.4.6.2 requires verification of SG OPERABILITY.
SG OPERABILITY is verified by ensuring that the secondary side narrow range water level is[17]%.If the SG secondary side narrow range water level is<[17]%, the tubes may become uncovered and the associated loop may not be of proViding the heat sink necessary for removal of decay heat.Uhe 12 hour Frequency is considered adequate in view of other indications available in the control room to alert the operator to the loss of SG level.',L..>-r ,', t".'WOGSTS Rev.3.1, 12/01/05 RCS Loops - MODE 4 B 3.4.6 BASES SURVEILLANCE REQUIREMENTS (continued) Verification that each required pump is OPERABLE ensures that an additional RCS or RHR pump can be placed in operation, if needed, to maintain decay heat removal and reactor coolant circulation. Verification is performed by verifying proper breaker alignment and power available to each required pump. Alternatively, verification that a pump is in operation also verifies proper breaker alignment and power availability.
Ehe Frequency of 7 days is considered reasonable in view of other administrative controls available and has been shown to be acceptable by operating experience.
This SR is modified by a Note that states the SR is not required to be performed until 24 hours after a required pump is not in operation. REFERENCES None.
WOG STS Rev. 3.1, 12/01/05 RCS Loops-MODE 4 B 3.4.6 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.4.6.3 Verification that each required pump is OPERABLE ensures that an additional RCS or RHR pump can be placed in operation, if needed, to maintain decay heat removal and reactor coolant circulation.
Verification is performed by verifying proper breaker alignment and power available to each required pump.Alternatively, verification that a pump is in operation also verifies proper breaker alignment and power availability.
Lthe Frequency of 7 days is considered reasonable in view of other administrative controls available and has been shown to be acceptable by operating experience.
This SR is modified by a Note that states the SR is not required to be performed until 24 hours after a required pump is not in operation.
REFERENCES WOGSTS None.B 3.4.6-5 Rev.3.1, 12/01/05 RCS Loops - MODE 5, Loops Filled B 3.4.7 BASES ACTIONS A.l, A.2, B.1 and 8.2 If one RHR loop is OPERABLE and either the required SGs have secondary side water levels < [17]%, or one required RHR loop is inoperable, redundancy for heat removal is lost. Action must be initiated immediately to restore a second RHR loop to OPERABLE status or to restore the required SG secondary side water levels. Either Required Action will restore redundant heat removal paths.
The immediate Completion Time reflects the importance of maintaining the availability of two paths for heat removal. C.l and C.2 If a required RHR loop is not in operation, except during conditions permitted by Note 1, or if no required loop is OPERABLE, all operations involving introduction of coolant into the RCS with boron concentration less than required to meet the minimum SDM of LC0 3.1 .I must be suspended and action to restore one RHR loop to OPERABLE status and operation must be initiated. Suspending the introduction of coolant into the RCS of coolant with boron concentration less than required to meet the minimum SDM of LC0 3.1 .I is required to assure continued safe operation. With coolant added without forced circulation, unmixed coolant could be introduced to the core, however coolant added with boron concentration meeting the minimum SDM maintains acceptable margin to subcritical operations.
The immediate Completion Times reflect the importance of maintaining operation for heat removal. SURVEILLANCE SR 3.4.7.1 REQUIREMENTS This SR requires loop is in operation.
Verification or pump status monitoring, which help ensure that forced flow is providing heat removal.
Ehe Frequency of 12 hours is sufficient considering other indications and alarms available to the operator in the control room to monitor RHR loop performance.
----a - Verifying that at least two SGs are OPERABLE by ensuring their secondary side narrow range water levels are 2 [17]% ensures an alternate decay heat removal method via natural circulation in the event that the second RHR loop is not OPERABLE. If both RHR loops are OPERABLE, this Surveillance is not needed. Ehe 12 hour Frequency is considered adequate in view of other indications available in the control room to alert the operator to the loss of SG level.\ Gca WOG STS B 3.4.7-4 Rev. 3.1, 12/01/05 BASES ACTIONS SURVEILLANCE REQUIREMENTS RCS Loops-MODE 5, Loops Filled B 3.4.7 A.1, A.2, B.1 and B.2 If one RHR loop is OPERABLE and either the required SGs have secondary side water levels<[17]%, or one required RHR loop is inoperable, redundancy for heat removal is lost.Action must be initiated immediately to restore a second RHR loop to OPERABLE status or to restore the required SG secondary side water levels.Either Required Action will restore redundant heat removal paths.The immediate Completion Time reflects the importance of maintaining the availability of two paths for heat removal.C.1 and C.2 If a required RHR loop is not in operation, except during conditions permitted by Note 1, or if no required loop is OPERABLE, all operations involving introduction of coolant into the RCS with boron concentration less than required to meet the minimum SOM of LCO 3.1.1 must be suspended and action to restore one RHR loop to OPERABLE status and operation must be initiated.
Suspending the introduction of coolant into the RCS of coolant with boron concentration less than required to meet the minimum SOM of LCO 3.1.1 is required to assure continued safe operation.
With coolant added without forced circulation, unmixed coolant could be introduced to the core, however coolant added with boron concentration meeting the minimum SDM maintains acceptable margin to subcritical operations.
The immediate Completion Times reflect the importance of maintaining operation for heat removal.SR 3.4.7.1 This SR requires verification@VerJ 1'(houaxhat the required loop is in operation.
Verification includes trow rate, temperature, or pump status monitoring, which help ensure that forced flow is providing heat removal.ille Frequency of 12 hours is sufficient considering other indications and alarms available to the operator in the control room to monitor RHR loop performance.
SR 3.4.7.2 Verifying that at least two SGs are OPERABLE by ensuring their secondary side narrow range water levels are[17J%ensures an alternate decay heat removal method via natural circulation in the event that the second RHR loop is not OPERABLE.If both RHR loops are OPERABLE, this Surveillance is not needed.[he 12 hour Frequency is considered adequate in view of otherindicationsavailable in the control room to alert the operator to the loss of 5G WOG STS B3.4.7-4 Rev.3.1,12/01/05 RCS Loops - MODE 5, Loops Filled B 3.4.7 BASES SURVEILLANCE REQUIREMENTS (continued) Verification that each required RHR pump is OPERABLE ensures that an additional pump can be placed in operation, if needed, to maintain decay heat removal and reactor coolant circulation. Verification is performed by verifying proper breaker alignment and power available to each required RHR pump. Alternatively, verification that a pump is in operation also verifies proper breaker alignment and power availability. If secondary side water level is 2 [17]% in at least two SGs, this Surveillance is not needed. Ehe Frequency of 7 days is considered reasonable in view of other administrative controls available and has been shown to be acceptable by operating experience.
v~5ed2.. This SR is modified by a Note that states the SR is not required to be performed until 24 hours after a required pump is not in operation.
REFERENCES
: 1. NRC Information Notice 95-35, "Degraded Ability of Steam Generators to Remove Decay Heat by Natural Circulation." WOG STS Rev. 3.1, 12101105 RCS Loops-MODE 5, Loops Filled B 3.4.7 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.4.7.3 Verification that each required RHR pump is OPERABLE ensures that an additional pump can be placed in operation, if needed.to maintain decay heat removal and reactor coolant circulation.
Verification is performed by verifying proper breaker alignment and power available to each required RHR pump.Alternatively, verification that a pump is in operation also verifies proper breaker alignment and power availability.
If secondary side water level is<::[17]%in at least two SGs, this Surveillance is not needed.[he Frequency of 7 days is considered reasonable in view of other administrative controls available and has been shown to be acceptable by operating experience.SCr" E 2.)This SR is modified by a Note that states the SR is not required to be performed until 24 hours after a required pump is not in operation.
REFERENCES 1.NRC Information Notice 95-35,"Degraded Ability of Steam Generators to Remove Decay Heat by Natural Circulation." WOGSTS B 3.4.7-5 Rev.3.1,12/01/05 RCS Loops - MODE 5, Loops Not Filled B 3.4.8 BASES ACTIONS (continued) criticality must not be reduced in this type of operation. Suspending the introduction of coolant into the RCS of coolant with boron concentration less than required to meet the minimum SDM of LC0 3.1.1 is required to assure continued safe operation. With coolant added without forced circulation, unmixed coolant could be introduced to the core, however coolant added with boron concentration meeting the minimum SDM maintains acceptable margin to subcritical operations. The immediate Completion Time reflects the importance of maintaining operation for heat removal. The action to restore must continue until one loop is restored to OPERABLE status and operation.
SURVEILLANCE SR 3.4.8.1 REQUIREMENTS This SR requires verificationt@jhburs)that the required loop is in operation. Verification includes flow rate, temperature, or pump status monitoring, which help ensure that forced flow is providing heat removal.
phe Frequency of 12 hours is sufficient considering other indications and alarms available to the operator in the control room to monitor RHR loop performance.
<- % *k~z;;~T~ Verification that each required pump is OPERABLE ensures that an additional pump can be placed in operation, if needed, to maintain decay heat removal and reactor coolant circulation.
Verification is performed by verifying proper breaker alignment and power available to each required pump. Alternatively, verification that a pump is in operation also verifies proper breaker alignment and power availability.
Ehe Frequency of 7 days is considered reasonable in view of other administrative controls available and has been shown to be acceptable by operating This SR is modified by a Note that states the SR is not required to be performed until 24 hours after a required pump is not in operation. REFERENCES None.
WOG STS Rev. 3.0, 03/31/04 RCS Loops-MODE 5, Loops Not Filled B 3.4.8 BASES ACTIONS (continued) criticality must not be reduced in this type of operation.
Suspending the introduction of coolant into the RCS of coolant with boron concentration less than required to meet the minimum SDM of LCO 3.1.1 is required to assure continued safe operation.
With coolant added without forced circulation, unmixed coolant could be introduced to the core, however coolant added with boron concentration meeting the minimum SOM maintains acceptable margin to subcritical operations.
The immediate Completion Time reflects the importance of maintaining operation for heat removal.The action to restore must continue until one loop is restored to OPERABLE status and operation.
SURVEILLANCE REQUIREMENTS REFERENCES SR 3.4.8.1 This SR requires verification (lvery)12 tt>UfS>that the required loop is in operation.
Verification includes flow rate, temperature.
or pump status monitoring, which help ensure that forced flow is providing heat removal.Uhe Frequency of 12 hours is sufficient considering other indications and alarms available to the operator in the control room to monitor RHR loop performance.
<-''''''a;-"--....." I'("Ser" t.2 ,)
SR 3.4.8.2 Verification that each required pump is OPERABLE ensures that an additional pump can be placed in operation, if needed, to maintain decay heat removal and reactor coolant circulation.
Verification is performed by verifying proper breaker alignment and power available to each required pump.Alternatively, verification that a pump is in operation also verifies proper breaker alignment and power availability.
{lhe Frequency of 7 days is considered reasonable in view of other administrative available and has been shown to be acceptable by operating experience.
This SR is modified by a Note that states the SR is not required to be performed until 24 hours after a required pump is not in operation.
None.WOGSTS B 3.4.8-3 Rev.3.0, 03/31/04 Pressurizer 6 3.4.9 BASES ACTIONS (continued)
C.1 and C.2 If one group of pressurizer heaters are inoperable and cannot be restored in the allowed Completion Time of Required Action B.1, the plant must be brought to a MODE in which the LC0 does not apply.
To achieve this status, the plant must be brought to MODE 3 within 6 hours and to MODE 4 within 12 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.
SURVEILLANCE SR 3.4.9.1 REQUIREMENTS This SR requires that during steady state operation, pressurizer level is maintained below the nominal upper limit to provide a minimum space for a steam bubble. he Surveillance is performed by observing the indicated level.
2 The Frequency of 12 hours corresponds to verifying the parameter each shift. The 12 hour interval has been shown by operating practice to be sufficient to regularly assess level for any deviation and verify that operation is within safety analyses assumption of ensuring that a steam bubble exists in the pressurizer. Alarms are also available for early detection of abnormal level indications.
SR 3.4.9.2 ----------------------++-----------
REVIEWER'S NOTE ................................... The frequency for performing Pressurizer heater capacity testing shall be either 18 months or 92 days, depending on whether or not the plant has dedicated safety-related heaters. For dedicated safety-related heaters, which do not normally operate, 92 days is applied. For non-dedicated safety-related heaters, which normally operate, 18 months is applied. The SR is satisfied when the power supplies are demonstrated to be capable of producing the minimum power and the associated pressurizer heaters are verified to be at their design rating. This may be done by testing the power supply output and by performing an electrical check on heater element continuity and resistance.Ehe Frequency of 1181 months is considered adequate to detect heater degradation and has been shown by operating experience to be acceptable. -L~D WOG STS I3 3.4.9-4 Rev. 3.0, 03131 104 Pressurizer B 3.4.9 BASES ACTIONS (continued)
C.1 and C.2 If one group of pressurizer heaters are inoperable and cannot be restored in the allowed Completion Time of Required Action B.1, the plant must be brought to a MODE in which the LCO does not apply.To achieve this status, the plant must be brought to MODE 3 within 6 hours and to MODE 4 within 12 hours.The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.SURVEILLANCE REQUIREMENTS SR 3.4.9.1 This SR requires that during steady state operation, pressurizer level is maintained below the nominal upper limit to provide a minimum space for a steam bubble.Jhe Surveillance is performed by observing the indicated level.{Ihe Frequency of 12 hours corresponds to verifying the parameter each shift.The 12 hour interval has been shown by operating practice to be sufficient to regularly assess level for any deviation and verify that operation is within safety analyses assumption of ensuring that a steam bubble exists in the pressurizer.
Alarms are also available for early detection of abnormal level indications.(L.&#xa3;).-LJ15.e"t:<SR 3.4.9.2 lEW E R'S NOTE The frequency for performing Pressurizer heater capacity testing shall be either 18 months or 92 days, depending on whether or not the plant has dedicated heaters.For dedicated safety-related heaters, which do not normally operate, 92 days is applied.For heaters, which normally operate, 18 months is applied.The SR is satisfied when the power supplies are demonstrated to be capable of producing the minimum power and the associated pressurizer heaters are verified to be at their design rating.This may be done by testing the power supply output and by performing an electrical check on heater element continuity and resistance.l1he Frequency of[18]months is considered adequate to detect heater degradation and has been shown by operating experience to be acceptable.
WOGSTS B Rev.3.0, 03/31/04 Pressurizer B 3.4.9 BASES SURVEILLANCE REQUIREMENTS (continued)
[SR 3.4.9.3 This SR is not applicable if the heaters are permanently powered by Class 1 E power supplies. This Surveillance demonstrates that the heaters can be manually transferred from the normal to the emergency power supply and energized.Ehe Frequency of 18 months is based on a typical fuel and is consistent with similar verifications of emergency power REFERENCES 1. FSAR, Section [ 1. 2. NUREG-0737, November 1980. WOG STS Rev. 3.0, 03/31/04 Pressurizer B 3.4.9 BASES SURVEILLANCE REQUIREMENTS (continued)
[SR 3.4.9.3 This SR is not applicable if the heaters are permanently powered by Class1E power supplies.REFERENCES This Surveillance demonstrates that the heaters can be manually transferred from the normal to the emergency power supply and energized.
[ihe Frequency of 18 months is based on a typical fuel cycle and is consistent with similar verifications of emergency power supplies.]1.FSAR, Section[].2.NUREG-0737, November 1980.WOGSTS B 3.4.9-5 Rev.3.0, 03/31/04 Pressurizer PORVs B 3.4.1 1 BASES ACTIONS (continued)
If two [or three] block valve(s) are inoperable, it is necessary to restore at least one block valve within 2 hours. The Completion Time is reasonable, based on the small potential for challenges to the system during this time and provide the operator time to correct the situation. Required Action F.? is modified by a Note stating that the Required Action does not apply if the sole reason for the block valve being declared inoperable is a result of power being removed to comply with other Required Actions.
In this event, the Required Actions for inoperable PORV(s) (which require the block valve power to be removed once it is closed) are adequate to address the condition. While it may be desirable to also place the PORV(s) in manual control, this may not be possible for all causes of Condition B or E entry with PORV(s) inoperable and not capable of being manually cycled (e.g., as a result of failed control power fuse(s) or control switch malfunctions(s)).
G.l and G.2 If the Required Action of Condition F is not met, then the plant must be brought to a MODE in which the LC0 does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 4 within 12 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.
In MODES 4 and 5, automatic PORV OPERABILITY may be required. See LC0 3.4.12. SURVEILLANGE SR 3.4.1 1 .I REQUIREMENTS Block valve cycling verifies that the valve@) can be opened and closed if needed.Ehe basis for the Frequency of 92 days is the ASME Code (Ref. 3). +.- TwT$ This SR is modified by two Notes. Note 1 modifies this SR by stating that it is not required to be performed with the block valve closed in accordance with the Required Actions of this LCO. Opening the block valve in this condition increases the risk of an unisolable leak from the RCS since the PORV is already inoperable. Note 2 modifies this SR to allow entry into and operation in MODE 3 prior to performing the SR. This allows the test to be performed in MODE 3 under operating WOG STS B 3.4.1 1-6 Rev. 3.1, 12/01/05 Pressurizer PORVs B 3.4.11 BASES ACTIONS (continued)
If two[or three]block valve(s)are inoperable, it is necessary to restore at least one block valve within 2 hours.The Completion Time is reasonable, based on the small potential for challenges to the system during this time and provide the operator time to correct the situation.
Required Action F.1 is modified by a Note stating that the Required Action does not apply if the sole reason for the block valve being declared inoperable is a result of power being removed to comply with other Required Actions.In this event, the Required Actions for inoperable PORV(s)(which require the block valve power to be removed once it is closed)are adequate to address the condition.
While it may be desirable to also place the PORV(s)in manual control, this may not be possible for all causes of Condition B or E entry with PORV(s)inoperable and not capable of being manually cycled (e.g., as a result of failed control power fuse(s)or control switch malfunctions(s)).
G.1 and G.2 If the Required Action of Condition F is not met, then the plant must be brought to a MODE in which the LCO does not apply.To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 4 within 12 hours.The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.In MODES 4 and 5, automatic PORV OPERABILITY may be required.See LCO 3.4.12.SURVEILLANCE REQUIREMENTS SR 3.4.11.1 Block valve cycling verifies that the valve(s)can be opened and closed if needed.@1e basis for the Frequency of 92 days is the ASME Code (Ref.3).
This SR is modified by two Notes.Note 1 modifies this SR by stating that it is not required to be performed with the block valve closed in accordance with the Required Actions of this LCO.Opening the block valve in this condition increases the risk of an unisolable leak from the RCS since the PORV is already inoperable.
Note 2 modifies this SR to allow entry into and operation in MODE 3 prior to performing the SR.This allows the test to be performed in MODE 3 under operating WOGSTS B 3.4.11-6 Rev.3.1,12/01/05 Pressurizer PORVs B 3.4.1 1 BASES SURVEILLANCE REQUIREMENTS (continued) temperature and pressure conditions, prior to entering MODE 1 or
: 2. [In accordance with Reference 4, administrative controls require this test be performed in MODE 3 or 4 to adequately simulate operating temperature and pressure effects on PORV operation.]
SR 3.4.1 1.2 requires a complete cycle of each PORV. Operating a PORV through one complete cycle ensures that the PORV can be manually actuated for mitigation of an SGTR.E~~ Frequency of The Note modifies this SR to allow entry into and operation in MODE 3 prior to performing the SR. This allows the test to be performed in MODE 3 under operating temperature and pressure conditions, prior to entering MODE 1 or
: 2. [In accordance with Reference 4, administrative controls require this test be performed in MODE 3 or 4 to adequately simulate operating temperature and pressure effects on PORV operation.] Operating the solenoid air control valves and check valves on the air accumulators ensures the PORV control system actuates properly when called upon.
rhe Frequency of [I81 months is based on a typical refueling cycleand the Frequency of the other Surveillances used to demonstrate PORV OPERABILITY.
] e%-h<Tx"&T<) This Surveillance is not required for plants with permanent 1 E power supplies to the valves. The Surveillance demonstrates that emergency power can be provided and is performed by transferring power from normal to emergency supply and cycling the valves.
Ehe Frequency of
[A81 months is based on a typical refueling cycle and industry accepted practice.
] + WOG STS B 3.4.1 1-7 Rev. 3.1, 12/01/05 Pressurizer PORVs B 3.4.11 BASES SURVEILLANCE REQUIREMENTS (continued) temperature and pressure conditions, prior to entering MODE 1 or 2.[In accordance with Reference 4, administrative controls require this test be performed in MODE 3 or 4 to adequately simulate operating temperature and pressure effects on PORV operation.]
SR 3.4.11.2 SR 3.4.11.2 requires a complete cycle of each PORV.Operating a PORV through one complete cycle ensures that the PORV can be manually actuated for mitigation of an SGTR.(ihe Frequency of[18]months is based on a tical refueling cycle and industry accepted
'2 The Note modifies this SR to allow entry into and operation in MODE 3 prior to performing the SR.This allows the test to be performed in MODE 3 under operating temperature and pressure conditions, prior to entering MODE 1 or 2.[In accordance with Reference 4, administrative controls require this test be performed in MODE 3 or 4 to adequately simulate operating temperature and pressure effects on PORV operation.]
[SR 3.4.11.3 Operating the solenoid air control valves and check valves on the air accumulators ensures the PORV control system actuates properly when called upon.me Frequency of[18]months is based on a typical refueling cycle and the Frequency of the other Surveillances used to demonstrate PORV OPERABILITY.]
[SR 3.4.11.4 This Surveillance is not required for plants with permanent1E power supplies to the valves.The Surveillance demonstrates that emergency power can be provided and is performed by transferring power from normal to emergency supply and cycling the valves.Uhe Frequency of[18]months is based on a typical refueling cycle and industry accepted practice.]WOGSTS B3.4.11-7 Rev.3.1, 12/01/05 LTOP System B 3.4.12 BASES ACTIONS (continued)
The consequences of operational events that will overpressurize the RCS are more severe at lower temperature (Ref. 7). Thus, with one of the two RCS relief valves inoperable in MODE 5 or in MODE 6 with the head on, the Completion Time to restore two valves to OPERABLE status is 24 hours.
The Completion Time represents a reasonable time to investigate and repair several types of relief valve failures without exposure to a lengthy period with only one OPERABLE RCS relief valve to protect against overpressure events.
The RCS must be depressurized and a vent must be established within 12 hours when: a. Both required RCS relief valves are inoperable, b. A Required Action and associated Completion Time of Condition A, [B], D, E, or F is not met, or
: c. The LTOP System is inoperable for any reason other than Condition A, [B], C, D, E, or F. The vent must be sized r [2.07] square inches to ensure that the flow capacity is greater than that required for the worst case mass input transient reasonable during the applicable MODES. This action is needed to protect the RCPB from a low temperature overpressure event and a possible brittle failure of the reactor vessel. The Completion Time considers the time required to place the plant in this Condition and the relatively low probability of an overpressure event during this time period due to increased operator awareness of administrative control requirements.
SURVEILLANCE SR 3.4.12.1, TSR 3.4.12.21, and SR 3.4.12.3 REQUIREMENTS To minimize the potential for a low temperature overpressure event by limiting the mass input capability, a maximum of [one] [HPI] pump [and a maximum of one charging pump] are verified incapable of injecting into the RCS and the accumulator discharge isolation valves are verified closed and locked out.
WOG STS B 3.4.12-10 Rev. 3.1, 12/01/05 LTOP System 83.4.12 BASES ACTIONS (continued)
The consequences of operational events that will overpressurize the RCS are more severe at lower temperature (Ref.7).Thus, with one of the two RCS reliefvalvesinoperable in MODE 5 or in MODE 6 with the head on, the Completion Time to restore two valves to OPERABLE status is 24 hours.The Completion Time represents a reasonable time to investigate and repair several types of relief valve failures without exposure to a lengthy period with only one OPERABLE RCS relief valve to protect against overpressure events.The RCS must be depressurized and a vent must be established within 12 hours when: a.Both required RCS relief valves are inoperable, b.A Required Action and associated Completion Time of Condition A,[B], 0, E, or F is not met, or c.The L TOP System is inoperable for any reason other than Condition A,[B], C, 0, E, or F.The vent must be sized[2.07]square inches to ensure that the flow capacity is greater than that required for the worst case mass input transient reasonable during the applicable MODES.This action is needed to protect theRCPB from a low temperature overpressure event and a possible brittle failure of the reactor vessel.The Completion Time considers the time required to place the plant in this Condition and the relatively low probability of an overpressure event during this time period due to increased operator awareness of administrative control requirements.
SURVEILLANCE REQUIREMENTS SR 3.4.12.1,[SR 3.4.12.2].
and SR 3.4.12.3 To minimize the potential for a low temperature overpressure event by limiting the mass input capability, a maximum of[one][HPI]pump[and a maximum of one charging pump]are verified incapable of injecting into the RCS and the accumulator discharge isolation valves are verified closed and locked out.WOGSTS B 3.4.12-10 Rev.3.1,12/01/05 LTOP System B 3.4.12 BASES SURVEILLANCE REQUIREMENTS (continued)
The [HPI] pump[s] and charging pump[s] are rendered incapable of injecting into the RCS through removing the power from the pumps by racking the breakers out under administrative control. An alternate method of LTOP control may be employed using at least two independent means to prevent a pump start such that a single failure or single action will not result in an injection into the RCS. This may be accomplished through the pump control switch being placed in [pull to lock] and at least one valve in the discharge flow path being closed.
Ehe Frequency of 12 hours is sufficient, considering other indications and alarms available to the o~erator in the control room. to verifv the reauired status of the equipment.
&----. -@zGrm Each required RHR suction relief valve shall be demonstrated OPERABLE by verifying its RHR suction valve and RHR suction isolation valves are open and by testing it in accordance with the lnservice Testing Program. (Refer to SR 3.4.12.7 for the RHR suction isolation valve Surveillance.)
This Surveillance is only required to be performed if the RHR suction relief valve is being used to meet this LCO. I___- _ .-_..-U*. -haw s)~ The RHR suction valve is verified to be opened- Ehe Frequenc~s considered adequate in view of other administrative controls such aslvalve status indications available to the operator in the control room that verify the RHR suction valve remains open. 51 Cv\TeT*a The ASME Code (Ref.
8), test p& lnservice Testing Program verifies OPERABILITY by proving proper relief valve mechanical motion and by measuring and, if required, adjusting the lift setpoint.
] The RCS vent of 2 [2.07] square inches is proven OPERABLE by verifying its open conditionFther:
: a. Once every 12 hours for a valve that is not locked (valves that are sealed or secured in the open position are considered "locked" in this context) or
: b. Once every 31 days for other vent path(s) (e.g., a vent valve that is locked, sealed, or secured in position).
A removed pressurizer safety valve or open manway also fits this category.
WOG STS B 3,4.12-1 I Rev. 3.1, 12/01/05 LTOP System B 3.4.12 BASES SURVEILLANCE REQUIREMENTS (continued)
The[HPI]pump[s]and charging pump[s]are rendered incapable of injecting into the RCS through removing the power from the pumps by racking the breakers out under administrative control.An alternate method of L TOP control may be employed using at least two independent means to prevent a pump start such that a single failure or single action will not result in an injection into the RCS.This may be accomplished through the pump control switch being placed in[pull to lock]and at least one valve in the discharge flow path being closed.[[he Frequency of 12 hours is sufficient, considering other indications and alarms available to the operator in the control room, to verify the required status of the equipment.
__[SR 3.4.12.4 Each required RHR suction relief valve shall be demonstrated OPERABLE by verifying its RHR suction valve and RHR suction isolation valves are open and by testing it in accordance with the Inservice Testing Program.(Refer to SR 3.4.12.7 for the RHR suction isolation valve Surveillance.)
This Surveillance is only required to be performed if the RHR suction relief valve is being used to meet this LCO.rr If)The RHR suction valve is verified to be
[be lOL I-.._
considered adequate in view of other administrative controls such as valve status indications available to the operator in the control room that verify the RHR suction valve remains open.
The ASME Code (Ref.8), test per Inservice Testing Program verifies OPERABILITY by proving proper relief valve mechanical motion and by measuring and, if required, adjusting the lift setpoint.]SR 3.4.12.5 The RCS vent of[2.07]square inches is proven OPERABLE by verifying its open condition@ther:
a.Once every 12 hours for a valve that is not locked (valves that are sealed or secured in the open position are considered"locked" in this context)or b.Once every 31 days for other vent path(s)(e.g., a vent valve that is locked, sealed, or secured in position).
A removed pressurizer safety valve or open manway also fits this category..
V WOG STS 83.4.12-11 Rev.3.1, 12/01/05 LTOP System B 3.4.12 BASES SURVEILLANCE REQUIREMENTS (continued) The passive vent path arrangement must only be open to be OPERABLE. This Surveillance is required to be met if the vent is being used to satisfy the pressure relief requirements of the LC0 3.4.12d. The PORV block valve must be verified ope<every 72hour3 to provide the flow path for each required PORV to perform its function when actuated.
The valve must be remotely verified open in the main control room. [This Surveillance is performed if the PORV satisfies the LCO.] The block valve is a remotely controlled, motor operated valve. The power to the valve operator is not required removed, and the manual operator is not required locked in the inactive position.
Thus, the block valve can be closed in the event the PORV develops excessive leakage or does not close (sticks open) after relieving an overpressure situation.
Ehe 72 hour Freauencv is considered adeauate in view of other G administrative co;~trols~available to the ope;ator in the control room, such as valve position indication, that verify that the PORV block valve remains Each required RHR suction relief valve shall be demonstrated OPERABLE by verifying its RHR suction valve and RHR suction isolation valve are open and by testing it in accordance with the lnservice Testing Program. (Refer to SR 3.4.12.4 for the RHR suction valve Surveillance and for a description of the requirements of the lnservice Testing Program.) This Surveillance is only performed if the RHR suction relief valve is being used to satisfy this LCO.]
e RHR suction isolation valve is verified locked open, valve operator removed, to ensure that accidental closure will not occur.
The "locked open" valve must be locally verified in its open position with the manual actuator locked in its inactive position.
Ehe 31 day Frequency is based on engineering judgment, is consistent with the procedural controls governing valve operation, and ensures correct valve position.
] L-J-j&rn WOG STS B 3.4.12-12 Rev. 3.1, 12/01/05 LTOP System B 3.4.12 BASES SURVEILLANCE REQUIREMENTS (continued)
The passive vent path arrangement must only be open to be OPERABLE.This Surveillance is required to be met if the vent is being used to satisfy the pressure relief requirements of the LCO 3.4.12d.SR 3.4.12.6 The PORV block valve must be verified oper0veryto provide the flow path for each required PORV to perform its function when actuated.The valve must be remotely verified open in the main control room.[This Surveillance is performed if the PORV satisfies the LCO.]The block valve is a remotely controlled, motor operated valve.The power to the valve operator is not required removed, and the manual operator is not required locked in the inactive position.Thus, the block valve can be closed in the event the PORV develops excessive leakage or does not close (sticks open)after relieving an overpressure situation.
[!he 72 hour Frequency is considered adequate in view of other administrative controls available to the operator in the control room, such as valve position indication, that verify that the PORV block valve remains
[SR 3.4.12.7 Each required RHR suction relief valve shall be demonstrated OPERABLE by verifying its RHR suction valve and RHR suction isolation valve are open and by testing it in accordance with the Inservice Testing Program.(Refer to SR 3.4.12.4 for the RHR suction valve Surveillance and for a description of the requirements of the Inservice Testing Program.)This Surveillance is only performed if the RHR suction relief valve is being used to satisfy this LCO.]$1 RHR suction isolation valve is verified locked open, WI power to the valve operator removed, to ensure that accidental closure will not occur.The"locked open" valve must be locally verified in its open position with the manual actuator locked in its inactive position.ahe 31 day Frequency is based on engineering judgment.is consistent with the procedural controls governing valve operation, and ensures correct valve position.]
WOG STS B 3.4.12-12 Rev.3.1,12/01/05 LTOP System B 3.4.12 BASES SURVEILLANCE REQUIREMENTS (continued)
Ghe 31 day Frequency Performance of a COT is required within 12 hours after decreasing RCS temperature to s [275"F] [LTOP arming temperature specified in the PTLR] and every 31 days on each required PORV to verify and, as necessary, adjust its lift setpoint.
A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable COT of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions. The COT will verify the setpoint is within the PTLR allowed maximum limits in the PTLR. PORV actuation could depressurize the RCS and is not required.
The 12 hour Frequency considers the unlikelihood of a low temperature overpressure event during this time9 been added indicating that this SR is required to be 12 hours after decreasing RCS cold leg temperature to 5 [275"F] [LTOP arming temperature specified in the PTLR]. The COT cannot be performed until in the LTOP MODES when the PORV lift setpoint can be reduced to the LTOP setting. The test must be performed within 12 hours after entering the LTOP MODES. considers operating experience with equipment reliability and matches the Performance of a CHANNEL CALIBRATION on each required PORV actuation channel is required every [I81 months to adjust the whole channel so that it responds and the valve opens within the required range REFERENCES
: 1. 10 CFR 50, Appendix G. 2. Generic Letter 88-1 1. 3. ASME, Boiler and Pressure Vessel Code, Section Ill. 4. FSAR, Chapter [I 51. 5. 10 CFR 50, Section 50.46. WOG STS B 3.4.12-13 Rev. 3.1, 12/01/05 LTOP System B 3.4.12 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.4.12.8<.8,a..st'J tak't}.,JriJ""'le'1 tA; SA'1;" l\Iulc?t6-
/LgZ>t[The 31 day Frequency considers experience with equipment
-"",---::::::::.:::--:::::::::=:::
[]he[18]month Frequency considers operating experience with equipment reliability and matches the typical refueling outage..---=REFERENCES Performance of a COT is required within 12 hours after decreasing RCS temperature to:5[275&deg;F][L TOP arming temperature specified in the PTLR]and every 31 days on each required PORV to verify and, as necessary, adjust its lift setpoint.A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable COT of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
The COT will verify the setpoint is within the PTLR allowed maximum limits in the PTLR.PORV actuation could depressurize the RCS and is not required.The 12 hour Frequency considers the unlikelihood of a low temperature event during thisA Note has been added indicating that this SR is required to be performed 12 hours after decreasing RCS cold leg temperature to:5[275&deg;F][L TOP arming temperature specified in the PTLR].The COT cannot be performed until in the L TOP MODES when the PORV lift setpoint can be reduced to the LTOP setting.The test must be performed within 12 hours after entering the LTOP MODES.SR 3.4.12.9 Performance of a CHANNEL CALIBRATION on each required PORV actuation channel is required every[18]months to adjust the whole channel so that it responds and the valve opens within the required range and accuracy to known input.1.10 CFR 50, Appendix G.2.Generic Letter 88-11.3.ASME, Boiler and Pressure Vessel Code, Section III.4.FSAR, Chapter[15].5.10 CFR 50, Section 50.46.WOGSTS Rev.3.1, 12/01/05 BASES RCS Operational LEAKAGE B 3.4.13 SURVEILLANCE REQUIREMENTS (continued)
The RCS water inventory balance must be met with the reactor at steady state operating conditions (stable temperature, power level, pressurizer and makeup tank levels, makeup and letdown, [and RCP seal injection and return flows]).
The Surveillance is modified by two Notes. Note 1 states that this SR is not required to be performed until 12 hours after establishing steady state operation.
The 12 hour allowance provides sufficient time to collect and process all necessary data after stable plant conditions are established. Steady state operation is required to perform a proper inventory balance since calculations during maneuvering are not useful. For RCS operational LEAKAGE determination by water inventory balance, steady state is defined as stable RCS pressure, temperature, power level, pressurizer and makeup tank levels, makeup and letdown, and RCP seal injection and return flows. An early warning of pressure boundary LEAKAGE or unidentified LEAKAGE is provided by the automatic systems that monitor the containment atmosphere radioactivity and the containment sump level. It should be noted that LEAKAGE past seals and gaskets is not pressure boundary LEAKAGE. These leakage detection systems are specified in LC0 3.4.15, "RCS Leakage Detection Instrumentation." Note 2 states that this SR is not applicable to primary to secondary LEAKAGE because LEAKAGE of 150 gallons per day cannot be measured accurately by an RCS water inventory balance.
Ge 72 hour Frequency is a reasonable interval to trend LEAKAGE and recognizes the importance of early leakage detection in the prevention of
---*-, +. *.* *." accidents.
&--+U< r* 'j jmrf L This SR verifies that primary to secondary LEAKAGE is less or equal to 150 gallons per day through any one SG. Satisfying the primary to secondary LEAKAGE limit ensures that the operational LEAKAGE performance criterion in the Steam Generator Program is met. If this SR is not met, compliance with LC0 3.4.20, "Steam Generator Tube Integrity," should be evaluated.
The 150 gallons per day limit is measured at room temperature as described in Reference
: 5. The operational LEAKAGE rate limit applies to LEAKAGE through any one SG. If it is not practical to assign the LEAKAGE to an individual SG, all the primary to secondary LEAKAGE should be conservatively assumed to be from one SG. WOG STS B 3.4.1 3-5 Rev. 3.1, 12/01/05 RCS Operational LEAKAGE B3.4.13 BASES SURVEILLANCE REQUIREMENTS (continued)
The RCS water inventory balance must be met with the reactor at steady state operating conditions (stable temperature, power level, pressurizer and makeup tank levels, makeup and letdown,[and RCP seal injection and return flows]).The Surveillance is modified by two Notes.Note 1 states that this SR is not required to be performed until 12 hours after establishing steady state operation.
The 12 hour allowance provides sufficient time to collect and process all necessary data after stable plant conditions are established.
Steady state operation is required to perform a proper inventory balance since calculations during maneuvering are not useful.For RCS operational LEAKAGE determination by water inventory balance, steady state is defined as stable RCS pressure, temperature, power level, pressurizer and makeup tank levels, makeup and letdown, and RCP seal injection and return flows.An early warning of pressure boundary LEAKAGE or unidentified LEAKAGE is provided by the automatic systems that monitor the containment atmosphere radioactivity and the containment sump level.It should be noted that LEAKAGE past seals and gaskets is not pressure boundary LEAKAGE.These leakage detection systems are specified in LCO 3.4.15,"RCS Leakage Detection Instrumentation." Note 2 states that this SR is not applicable to primary to secondary LEAKAGE because LEAKAGE of 150 gallons per day cannot be measured accurately by an RCS water inventory balance.rr;,e 72 hour Frequency is a reasonable interval to trend LEAKAGE and recognizes the importance of early leakage detection in the prevention of accidents.
SR 3.4.13.2 This SR verifies that primary to secondary LEAKAGE is less or equal to 150 gallons per day through anyone SG.Satisfying the primary to secondary LEAKAGE limit ensures that the operational LEAKAGE performance criterion in the Steam Generator Program is met.If this SR is not met, compliance with LCO 3.4.20,"Steam Generator Tube Integrity," should be evaluated.
The 150 gallons per day limit is measured at room temperature as described in Reference 5.The operational LEAKAGE rate limit applies to LEAKAGE through anyone SG.If it is not practical to assign the LEAKAGE to an individual SG, all the primary to secondary LEAKAGE should be conservatively assumed to be from one SG.WOGSTS B 3.4.13-5 Rev.3.1, 12/01/05 RCS Operational LEAKAGE B 3.4.13 BASES SURVEILLANCE REQUIREMENTS (continued) The Surveillance is modified by a Note which states that the Surveillance is not required to be performed until 12 hours after establishment of steady state operation.
For RCS primary to secondary LEAKAGE determination, steady state is defined as stable RCS pressure, temperature, power level, pressurizer and makeup tank levels, makeup and letdown, and RCP seal injection and return flows. Ehe Surveillance Frequency of 72 hours is a reasonable interval to trend primary to secondary LEAKAGE and recognizes the importance of early emical grab sampling in accordance with th REFERENCES I 10 CFR 50, Appendix A, GDC 30. 2. Regulatory Guide 1.45, May 1973. 3. FSAR, Section [15]. 4. NEI 97-06, "Steam Generator Program Guidelines." 5. EPRI, "Pressurized Water Reactor Primary-to-Secondary Leak Guidelines." WOG STS Rev. 3.1, 12/01/05 RCS Operational LEAKAGE B 3.4.13 BASES SURVEILLANCE REQUIREMENTS (continued)
The Surveillance is modified by a Note which states that the Surveillance is not required to be performed until 12 hoursafterestablishment of steady state operation.
For RCS primary to secondary LEAKAGE determination, steady state is defined as stable RCS pressure, temperature, power level, pressurizer and makeup tank levels, makeup and letdown, and RCP seal injection and return flows.Uhe Surveillance Frequency of 72 hours is a reasonable interval to trend primary to secondary LEAKAGE and recognizes the importance of early leakage detection in the prevention of accidents/D"1l.e_8rim&sect;'.fl:
to._secondary LEAKAGE is determined using continuous process radiation monitors or radiochemical grab sampling in accordance with guidelines (Ref.5).REFERENCES 1.10 CFR 50, Appendix A, GOC 30.2.Regulatory Guide 1.45, May 1973.3.FSAR, Section[15].4.NEI 97-06,"Steam Generator Program Guidelines." 5.EPRI,"Pressurized Water Reactor Primary-to-Secondary Leak Guidelines." WOG STS B 3.4.13-6 Rev.3.1,12/01/05 BASES SURVEILLANCE REQUIREMENTS RCS PIV Leakage B 3.4.14 SR 3.4.14.1 Performance of leakage testing on each RCS PIV or isolation valve used to satisfy Required Action A.1 and Required Action A.2 is required to verify that leakage is below the specified limit and to identify each leaking valve.The leakage limit of 0.5 gpm per inch of nominal valve diameter up to 5 gpm maximum applies to each valve.Leakage testing requires a stable pressure condition.
For the two PIVs in series, the leakage requirement applies to each valve individually and not to the combined leakage across both valves.If the PIVs are not individually leakage tested, one valve may have failed completely and not be detected if the other valve in series meets the leakage requirement.
In this situation, the protection rovided redundant valves would be lost.Ci)_blA.+I\I\q Testing is to be performed the plant does not go into MODE 5 for at least 7 days.he[18 month]Frequency is consistent with 10 CFR 50.55a(g)(Ref.8)as contained in the Inservice Testing Program, is within freguency allowed by the American Society of Mechanical Engineers (ASME)Code (Ref.7), and is based on the need to perform such surveillances under the conditions that apply during an outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power.
4)In addition, testing must be performed once after the valve has been opened by flow or exercised to ensure tight reseating.
PIVs disturbed in the performance of this Surveillance should also be tested unless documentation shows that an infinite testing loop cannot practically be avoided.Testing must be performed within 24 hours after the valve has been reseated.Within 24 hours is a reasonable and practical time limit for performing this test after opening or reseating a valve.The leakage limit is to be met at the RCS pressure associated with MODES 1 and 2.This permits leakage testing at high differential pressures with stable conditions not possible in the MODES with lower pressures.
Entry into MODES 3 and 4 is allowed to establish the necessary differential pressures and stable conditions to allow for performance of this Surveillance.
The Note that allows this provision is complementary to the Frequency of prior to entry into MODE 2 whenever the unit has been in MODE 5 for 7 days or more, if leakage testing has not been performed in the previous 9 months.In addition, this Surveillance is not required to WOGSTS B 3.4.14-5 Rev.3.1,12/01/05 BASES SURVEILLANCE REQUIREMENTS RCS PIV Leakage B3.4.14 SR 3.4.14.1 Performance of leakage testing on each RCS PIV or isolation valve used to satisfy Required Action A.1 and Required Action A.2 is required to verify that leakage is below the specified limit and to identify each leaking valve.The leakage limit of 0.5 gpm per inch of nominal valve diameter up to 5 gpm maximum applies to each valve.Leakage testing requires a stable pressure condition.
For the two PIVs in series, the leakage requirement applies to each valve individually and not to the combined leakage across both valves.If the PIVs are not individually leakage tested, one valve may have failed completely and not be detected if the other valve in series meets the leakage requirement.
In this situation, the protection rovided redundant valves would be lost.Ci)bcA-+MQ fK Testing is to be performed i::!r the plant does not go into MODE 5 for at least 7 days.he[18 month]Frequency is consistent with 10 CFR 50.55a(g)(Ref.8)as contained in the Inservice Testing Program, is within freguency allowed by the American Society of Mechanical Engineers (ASME)Code (Ref.7), and is based on the need to perform such surveillances under the conditions that apply during an outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power.In addition, testing must be performed once after the valve has been opened by flow or exercised to ensure tight reseating.
PIVs disturbed in the performance of this Surveillance should also be tested unless documentation shows that an infinite testing loop cannot practically be avoided.Testing must be performed within 24 hours after the valve has been reseated.Within 24 hours is a reasonable and practical time limit for performing this test after opening or reseating a valve.The leakage limit is to be met at the RCS pressure associated with MODES 1 and 2.This permits leakage testing at high differential pressures with stable conditions not possible in the MODES with lower pressures.
Entry into MODES 3 and 4 is allowed to establish the necessary differential pressures and stable conditions to allow for performance of this Surveillance.
The Note that allows this provision is complementary to the Frequency of prior to entry into MODE 2 whenever the unit has been in MODE 5 for 7 days or more, if leakage testing has not been performed in the previous 9 months.In addition, this Surveillance is not required to WOGSTS B 3.4.14-5 Rev.3.1,12/01/05 RCS PIV Leakage B 3.4.14 BASES SURVEILLANCE REQUIREMENTS (continued) be performed on the RHR System when the RHR System is aligned to the RCS in the shutdown cooling mode of operation.
PlVs contained in the RHR shutdown cooling flow path must be leakage rate tested after RHR is secured and stable unit conditions and the necessary differential pressures are established.
[ SR 3.4.14.2 and SR 3.4.14.3 Verifying that the RHR autoclosure interlocks are OPERABLE ensures that RCS pressure will not pressurize the RHR system beyond 125%
of its design pressure of I6001 psig. The interlock setpoint that prevents the valves from being opened is set so the actual RCS pressure must be < 14251 psig to open the valves. This setpoint ensures the RHR desi n pressure will not be exceeded and the RHR relief valves will not lift.
&he [I81 month Frequency is based on the need to perform the Surveillance under conditions that apply during a plant outage. ' The [I81 month Freauency is also acceptable based on consideration of the design reliability (and confirming operating experience) of the equipment.
These SRs are modified by Notes allowing the RHR autoclosure function to be disabled when usingthe RHR system suction relief valves for cold overpressure protection in accordance with SR 3.4.12.7.
] REFERENCES
: 1. 10 CFR 50.2. 2. 10 CFR 50.55a(c).
: 3. 10 CFR 50, Appendix A, Section V, GDC 55. 4. WASH-1400 (NUREG-75/014), Appendix V, 0ctober 1975. 5. NUREG-0677, May 1980. [ 6. Document containing list of PIVs. ] 7. ASME Code for Operation and Maintenance of Nuclear Power Plants. 8. 10 CFR 50.55a(n).
WOG STS Rev. 3.1, 12/01/05 RCS PIV Leakage B 3.4.14 BASES SURVEILLANCE REQUIREMENTS (continued) be performed on the RHR System when the RHR System is aligned to the RCS in the shutdown cooling mode of operation.
PIVs contained in the RHR shutdown cooling flow path must be leakage rate tested after RHR is secured and stable unit conditions and the necessary differential pressures are established.
[SR 3.4.14.2 and SR 3.4.14.3 Verifying that the RHR autoclosure interlocks are OPERABLE ensures that RCS pressure will not pressurize the RHR system beyond 125%of its design pressure of[600]psig.The interlock setpoint that prevents the valves from being opened is set so the actual RCS pressure must be<[425J psig to open the valves.This setpoint ensures the RHR pressure will not be exceeded and the RHR relief valves will not Iift.lI..he
[18]month Frequency is based on the need to perform the Surveillance under conditions that apply during a plant outage.'The[18]month Frequency is also acceptable based on consideration of the design reliability (and confirming operating experience) of the equipment.
m These SRs are modified by Notes allowing the RHR autoclosure function to be disabled when using the RHR System suction relief valves for cold overpressure protection in accordance with SR 3.4.12.7.]
REFERENCES 1.10 CFR 50.2.2.10 CFR 50.55a(c).
3.10 CFR 50, Appendix A, Section V, GDC 55.4.WASH-1400 (NUREG-75/014), Appendix V, October 1975.5.NUREG-0677, May 1980.[6.Document containing list of PIVs.]7.ASME Code for Operation and Maintenance of Nuclear Power Plants.8.10 CFR 50.55a(g).
WOGSTS B 3.4.14-6 Rev.3.1,12/01/05 RCS Leakage Detection Instrumentation B 3.4.15 BASES ACTIONS (continued)
[ D.l and D.2 With the required containment atmosphere radioactivity monitor and the required containment air cooler condensate flow rate monitor inoperable, the only means of detecting leakage is the containment sump monitor. This Condition does not provide the required diverse means of leakage detection. The Required Action is to restore either of the inoperable required monitors to OPERABLE status within 30 days to regain the intended leakage detection diversity.
The 30 day Completion Time ensures that the plant will not be operated in a reduced configuration for a lengthy time period.
] E.l and E.2 If a Required Action of Condition A, B, [C], or [Dl cannot be met, the plant must be brought to a MODE in which the requirement does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 5 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems. With all required monitors inoperable, no automatic means of monitoring leakage are available, and immediate plant shutdown in accordance with LC0 3.0.3 is required.
SURVEILLANCE SR 3.4.1 5.1 REQUIREMENTS SR 3.4.15.1 requires the performance of a CHANNEL CHECK of the required containment atmosphere radioactivity monitor. The check gives reasonable confidence that the channel is operating properly.
The Erequency of 12 hours is based on instrument reliability and is reasonable for detecting off normal conditions.
*b. WOG STS - B 3.4.15-5 Rev. 3.0, 03/31/04 RCS Leakage Detection Instrumentation B3.4.15 BASES ACTIONS (continued)
[D.1 and 0.2 With the required containment atmosphere radioactivity monitor and the required containment air cooler condensate flow rate monitor inoperable, the only means of detecting leakage is the containment sump monitor.This Condition does not provide the required diverse means of leakage detection.
The Required Action is to restore either of the inoperable required monitors to OPERABLE status within 30 days to regain the intended leakage detection diversity.
The 30 day Completion Time ensures that the plant will not be operated in a reduced configuration for a lengthy time period.]E.1 and E.2 If a Required Action of Condition A, B,[C], or[0]cannot be met, the plant must be brought to a MODE in which the requirement does not apply.To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 5 within 36 hours.The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.With all required monitors inoperable, no automatic means of monitoring leakage are available, and immediate plant shutdown in accordance with LCO 3.0.3 is required.SURVEILLANCE REQUIREMENTS SR 3.4.15.1 SR 3.4.15.1 requires the performance of a CHANNEL CHECK of the required containment atmosphere radioactivity monitor.The check gives reasonable confidence that the channel is operating properly.The[frequency of 12 hours is based on instrument reliability and is reasonable for detecting off normal conditions.....
:r: I"'ISef.A-WOGSTS B 3.4.15-5 Rev.3.0, 03/31/04 RCS Leakage Detection Instrumentation B 3.4.15 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.4.15.2 requires the performance of a COT on the required containment atmosphere radioactivity monitor. The test ensures that the monitor can perform its function in the desired manner.
A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable COT of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions. The test verifies the alarm setpoint and relative accuracy of the instrument string.
[fhe Frequency of 92 days considers instrument reliability, and operating experience has shown that it is proper for detecting degradation.
SR 3.4.15.3, ISR 3.4.15.4, and SR 3.4.15.52 These SRs require the performance of a CHANNEL CALIBRATION for each of the RCS leakage detection instrumentation channels.
The calibration verifies the accuracy of the instrument string, including the instruments located inside containment.
Fhe Frequency of 1181 months is a typical refueling cycle and considers channel reliability. Again, operating experience has proven that this Frequency is acceptable.
+ S, REFERENCES 1 10 CFR 50, Appendix A, Section IV, GDC 30. 2. Regulatory Guide 1.45. 3. FSAR, Section 1 1. WOG STS Rev. 3.0, 03/31/04 RCS Leakage Detection Instrumentation B 3.4.15 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.4.15.2 SR 3.4.15.2 requires the performance of a COT on the required containment atmosphere radioactivity monitor.The test ensures that the monitor can perform its function in the desired manner.A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable COT of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
The test verifies the alarm setpoint and relative accuracy of the instrument string.Uhe Frequency of 92 days considers instrument reliability, and operating experience has shown that it is proper for detecting degradation.
l SR 3.4.15.3,[SR 3.4.15.4, and SR 3.4.15.51 REFERENCES These SRs require the performance of a CHANNEL CALIBRATION for each of the RCS leakage detection instrumentation channels.The calibration verifies the accuracy of the instrument string, including the instruments located inside containment.
IThe Frequency of[18]months is a typical refueling cycle and considers channel reliability.
Again, operating experience has proven that this Frequency is acceptable..1.10 CFR 50, Appendix A, Section IV, GOC 30.(ErE2.Regulatory Guide 1.45.3.FSAR, Section[].WOG STS B 3.4.15-6 Rev.3.0, 03/31104 RCS Leakage Detection Instrumentation B 3.4.15 BASES - -- - ACTIONS (continued)
[ D. 1 and D.2 With the required containment atmosphere radioactivity monitor and the required containment air cooler condensate flow rate monitor inoperable, the only means of detecting leakage is the containment sump monitor. This Condition does not provide the required diverse means of leakage detection.
The Required Action is to restore either of the inoperable required monitors to OPERABLE status within 30 days to regain the intended leakage detection diversity.
The 30 day Completion Time ensures that the plant will not be operated in a reduced configuration for a lengthy time period. ] E.l and E.2 If a Required Action of Condition A, B, [C], or [Dl cannot be met, the plant must be brought to a MODE in which the requirement does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 5 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems. With all required monitors inoperable, leakage are available, and immediate LC0 3.0.3 is required. no automatic means of monitoring plant shutdown in accordance with SURVEILLANCE SR 3.4.15.1 REQUIREMENTS SR 3.4.15.1 requires the performance of a CHANNEL CHECK of the required containment atmosphere radioactivity monitor.
The c eck gives reasonable confidence that the channel is operating properly.
I! The Frequency of 12 hours is based on instrument reliability and is reasonable for detedhg off normal conditions+.~~~~ -rm -,nvrc*tBur..
a&=igJ WOG STS B 3.4.15-5 Rev. 3.0, 03/31/04 RCS Leakage Detection Instrumentation B 3.4.15 BASES ACTIONS (continued)
[D.1 and D.2 With the required containment atmosphere radioactivity monitor and the required containment air cooler condensate flow rate monitor inoperable, the only means of detecting leakage is the containment sump monitor.This Condition does not provide the required diverse means of leakage detection.
The Required Action is to restore either of the inoperable required monitors to OPERABLE status within 30 days to regain the intended leakage detection diversity.
The 30 day Completion Time ensures that the plant will not be operated in a reduced configuration for a lengthy time period.]E.1 and E.2 If a Required Action of Condition A, B,[C], or[D)cannot be met, the plant must be brought to a MODE in which the requirement does not apply.To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 5 within 36 hours.The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.With all required monitors inoperable, no automatic means of monitoring leakage are available, and immediate plant shutdown in accordance with LCO 3.0.3 is required.SURVEILLANCE SR 3.4.15.1 REQUIREMENTS SR 3.4,15.1 requires the performance of a CHANNEL CHECK of the required containment atmosphere radioactivity monitor.The gb.eck gives reasonable confidence that the channel is operating properly{lhe Frequency of 12 hours is based on instrument reliability and is reasonable for detecting off normal conditionsi.t""".,,, a.-...._--._...-'"".\"L'#)')"
WOGSTS B 3.4.15*5 Rev.3.0, 03/31/04 RCS Leakage Detection Instrumentation B 3.4. I5 BASES SURVEILLANCE REQUl REMENTS (continued)
SR 3.4.15.2 requires the performance of a COT on the required containment atmosphere radioactivity monitor. The test ensures that the monitor can perform its function in the desired manner.
A successful test of the required contact($) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable COT of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions. The test verifies the alarm setpoint and relative accuracy of the instrument string.
lf?e Frequency of 92 days considers instrument reliability, and operating experience has shown that it is proper for detecting degradati~n.<,,,.,~~,, SR 3.4.15.3.
TSR 3.4.15.4, and SR 3.4.15.51 These SRs require the performance of a CHANNEL CALIBRATION for each of the RCS leakage detection instrumentation channels.
The calibration verifies the accuracy of the instrument string, including the instruments located inside containment.
rhhe Frequency of 1181 months is a typical refueling cycle and considers channel reliability. Again, operating experience has proven that this Frequency is acceptable.%
-- - - REFERENCES I. I0 CFR 50, Appendix A, Section IV, GDC 30. 2. Regulatory Guide 1.45. 3. FSAR, Section [ 1. WOG STS Rev. 3.0, 03/31/04 RCS Leakage Detection Instrumentation B 3.4.15 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.4.15.2 These SRs require the performance of a CHANNEL CALIBRATION for each of the RCS leakage detection instrumentation channels.The calibration verifies the accuracy of the instrument string, including the instruments located inside containment.
[he Frequency of[18]months is a typical refueling cycle and considers channel reliability.
Again, operating experience has proven that this Frequency is acceptable.REFERENCES 1.10 CFR 50, Appendix A, Section IV, GDC 30.
2.Regulatory Guide 1.45.3.FSAR, Section[].WOGSTS B 3.4.15-6 Rev.3.0, 03/31/04 RCS Specific Activity B 3.4.16 BASES ACTIONS (continued) incorporated into the specific activity limit, the low probability of an event which is limiting due to exceeding this limit, and the ability to restore transient specific activity excursions while the plant remains at, or proceeds to power operation. With the gross specific activity in excess of the allowed limit, the unit must be placed in a MODE in which the requirement does not apply. The change within 6 hours to MODE 3 and RCS average temperature
< 500&deg;F lowers the saturation pressure of the reactor coolant below the setpoints of the main steam safety valves and prevents venting the SG to the environment in an SGTR event. The allowed Completion Time of 6 hours is reasonable, based on operating experience, to reach MODE 3 below 500&deg;F from full power conditions in an orderly manner and without challenging plant systems.
if a Required Action and the associated Completion Time of Condition A is not met or if the DOSE EQUIVALENT 1-131 is in the unacceptable region of Figure 3.4.16-1, the reactor must be brought to MODE 3 with RCS average temperature
< 500&deg;F within 6 hours. The Completion Time of 6 hours is reasonable, based on operating experience, to reach MODE 3 below 500&deg;F from full power conditions in an orderly manner and without challenging plant systems.
SURVEILLANCE SR 3.4.16.1 REQUIREMENTS SR 3.4.16.1 requires performing a gamma isoto of the gross specific activity of the reactor coola 0- While basically a quantitative measure of radionuclides with half lives longer than 15 minutes, excluding iodines, this measurement is the sum of the degassed gamma activities and the gaseous gamma activities in the sample taken. This Surveillance provides an indication of any increase in gross specific activity.
WOG STS B 3.4.16-4 Rev. 3.0, 03/31/04 RCS Specific Activity B 3.4.16 BASES ACTIONS (continued) incorporated into the specific activity limit, the low probability of an event which is limiting due to exceeding this limit, and the ability to restore transient specific activity excursions while the plant remains at, or proceeds to power operation.
With the gross specific activity in excess of the allowed limit, the unit must be placed in a MODE in which the requirement does not apply.The change within 6 hours to MODE 3 and RCS average temperature
<500 Q F lowers the saturation pressure of the reactor coolant below the setpoints of the main steam safety valves and prevents venting the SG to the environment in an SGTR event.The allowed Completion Time of 6 hours is reasonable, based on operating experience, to reach MODE 3 below 500 Q F from full power conditions in an orderly manner and without challenging plant systems.If a Required Action and the associated Completion Time of Condition A is not met or if the DOSE EQUIVALENT 1-131 is in the unacceptable region of Figure 3.4.16-1, the reactor must be brought to MODE 3 with RCS average temperature
<500 Q F within 6 hours.The Completion Time of 6 hours is reasonable, based on operating experience, to reach MODE 3 below 500 Q F from full power conditions in an orderly manner and without challenging plant systems.SURVEILLANCE REQUIREMENTS SR 3.4.16.1 SR 3.4.16.1 requires performing a gamma isotopic anal.....a measure of the gross specific activity of the reactor coolan at eatto e ever f[]ii'i)While basically a quantitative measure of radio nuclides with half lives longer than 15 minutes, excluding iodines, this measurement is the sum of the degassed gamma activities and the gaseous gamma activities in the sample taken.This Surveillance provides an indication of any increase in gross specific activity.WOGSTS B 3.4.16-4 Rev.3.0, 03/31/04 RCS Specific Activity B 3.4.76 BASES SURVEILLANCE REQUIREMENTS (continued) Trending the results of this Surveillance allows proper remedial action to be taken before reaching the LC0 limit under normal operating conditions. The Surveillance is ap Jicable in MODES 1 and 2, and in MODE 3 with T,, at least 500&deg;F.
e The 7 day Frequency considers the unlikelihood of a gross fuel failure during the time. This Surveillance is performed in MODE 1 only to ensure iodine remains within limit during normal operation and following fast power changes when fuel failure is more apt to occur. ahe 14 day Frequency is adequate to trend changes in the iodine activity level, considering gross activity is monitored every 7 days3The Frequency, between 2 and 6 hours after a power change 215% RTP within a 1 hour period, is established because the iodine levels peak during this time following fuel failure; samples at other times would provide inaccurate results. mical analysis for E determination is with the plant operating in MODE 1 rmination directly relates to the LC0 and is required to verify plant operation within the specified gross activity LC0 limit. The analysis for E is a measurement of the average energies per disintegration for isotopes with half lives longer than 15 minutes, excluding iodines. Frequency of 184 days recognizes E does not change rapidly.
$- This SR has been modified by a Note that indicates sampling is required to be performed within 31 days after a minimum of 2 effective full power days and 20 days of MODE 1 operation have elapsed since the reactor was last subcritical for at least 48 hours.
Th~s ensures that the radioactive materials are at equilibrium so the analysis for E is representative and not skewed by a crud burst or other similar abnormal event. REFERENCES
: 1. 10CFR100.11,1973.
: 2. FSAR, Section 115.6.31.
WOG STS Rev. 3.0, 03131104 RCS Specific Activity B 3.4.16 BASES SURVEILLANCE REQUIREMENTS (continued)
Trending the results of this Surveillance allows proper remedial action to be taken before reaching the LCO limit under normal operating conditions.
The Surveillance is in MODES 1 and 2, and in MODE 3 with T avg at least 500&deg;F.LI.he 7 day Frequency considers the unlikelihood of a gross fuel failure during the time.
\."I.rS err;, L SR 3.4.16.2 This Surveillance is performed in MODE 1 only to ensure iodine remains within limit during normal operation and following fast power changes when fuel failure is more apt to occur.lIhe 14 day Frequency is adequate to trend changes in the iodine activity level, considering gross activity is
.....
the iodine levels peak during this time following fuel failure;samples at other times would provide inaccurate results.SR 3.4.16.3 analysis for E determination is reqUired*i?18i#!YVos with the plant operating in MODE 1 equilibrium conditions.
e determination directly relates to the LCO and is required to verify plant operation within the specified gross activity LCO limit.The analysis for E is a measurement of the average energies per disintegration for isotopes with half lives longer than minutes, excluding iodines.Uhe Frequency of 184daysrecognizes E does not change rapidly.
*b This SR has been modified by a Note that indicates sampling is required to be performed within 31 days after a minimum of 2 effective full power days and 20 days of MODE 1 operation have elapsed since the reactor was lastsubcritical for at least 48 hours.This ensures that the radioactive materials are at equilibrium so the analysis for E is representative and not skewed by a crud burst or other similar abnormal event.REFERENCES 1.10 CFR 100.11, 1973.2.FSAR, Section[15.6.3].WOGSTS B 3.4.16-5 Rev.3.0, 03/31/04 RCS Loop Isolation Valves B 3.4.17 BASES SURVEILLANCE SR 3.4.17.1 REQUIREMENTS e ' The Surveillance is performedbtw>to ensure that the RCS loop isolation valves are open, with power removed from the loop isolation valve operators. The primary function of this Surveillance is to ensure that power is removed from the valve operators, since SR 3.4.4.1 of LC0 3.4.4, "RCS Loops - MODES 1 and 2," ensures that the loop isolation valves are open by verifying eve 12 hours that all loops are operating and circulating reactor coolantbhe Frequency of 31 days ensures that the required flow can be made available, is based on engineering judgment, and has proven to be acceptable. Operating experience has shown that the failure rate is so low that the 31 day Frequency is justified.
Jv. - - REFERENCES
: 1. FSAR, Section [I 5.2.61. WOG STS Rev. 3.0, 03131104 RCS Loop Isolation Valves B 3.4.17 BASES SR 3.4.17.1 FSAR, Section[15.2.6J.The Surveillance is ensure that the RCS loop isolation valves are open, with power removed from the loop isolation valve operators.
The primary function of this Surveillance is to ensure that power is removed from the valve operators, since SR 3.4.4.1 of LCO 3.4.4,"RCSLoops-MODES 1 and 2," ensures that the loop isolation valves are open by verifying hours that all loops are operating and circulating reactor coolant.\!he Frequency of 31 days ensures that the required flow can be made available, is based on engineering jUdgment, and has proven to be acceptable.
Operating experience has shown that the failure rate is so low that the 31 day Frequency is justified.
<c:-'1.SURVEILLANCE REQUIREMENTS REFERENCES WOGSTS B 3.4.17-3 Rev.3.0, 03/31/04 RCS Loops - Test Exceptions B 3.4.19 BASES SURVEILLANCE SR 3.4.19.1 REQUIREMENTS Verification that the power level is
< the P-7 interlock setpoint (10%) will ensure that the fuel design criteria are n t violated during the performance of the PHYSICS TESTS. 6 he Frequency of once per hour is adequate to ensure that the power level does not exceed the limit. Plant operations are conducted slowly during the performance of PHYSICS TESTS and monitorina the wower level once wer hour is sufficient to ensure that the powe~level'daes not exceed the limit.
& y-- &GzG-j) The power range and intermediate range neutron detectors.
P-10, and the P-13 interlock setpoint must be verified to be OPERABLE and adjusted to the proper value. The Low Power Reactor Trips Block, P-7 interlock, is actuated from either the Power Range Neutron Flux, P-10, or the Turbine Impulse Chamber Pressure, P-I3 interlock. The P-7 interlock is a logic Function with train, not channel identity.
A COT is performed prior to initiation of the PHYSICS TESTS. This will ensure that the RTS is properly aligned to provide the required degree of core protection during the performance of the PHYSICS TESTS.
A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable COT of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions. The SR 3.3.1.8 Frequency is sufficient for the power range and intermediate range neutron detectors to ensure that the instrumentation is OPERABLE before initiating PHYSICS TESTS. The Low Power Reactor Trips Block, P-7 interlock, must be verified to be OPERABLE in MODE 1 by LC0 3.3.1, "Reactor Trip System Instrumentation." The P-7 interlock is actuated from either the Power Range Neutron Flux, P-10, or the Turbine Impulse Chamber Pressure, P-I3 interlock. The P-7 interlock is a logic Function.
An ACTUATION LOGIC TEST is performed to verify OPERABILITY of the P-7 interlock prior to initiation of startup and PHYSICS TESTS. This will ensure that the RTS is properly functioning to provide the required degree of core protection during the performance of the PHYSICS TESTS. WOE STS B 3.4.1 9-3 Rev. 3.0, 03/31/04 RCS Loops-Test Exceptions B 3.4.19 BASES SURVEILLANCE SR 3.4.19.1 REQUIREMENTS Verification that the power level is<the P-7 interlock setpoint (10%)will ensure that the fuel design criteria are violated during the performance of the PHYSICS TESTS.Uhe Frequency of once per hour is adequate to ensure that the power level does not exceed the limit.Plant operations are conducted slowly during the performance of PHYSICS TESTS and monitoring the power level once per hour is sufficient to ensure that the power level does not exceed the limit.
SR 3.4.19.2 The power range and intermediate range neutron detectors.
P-10, and the P-13 interlock setpoint must be verified to be OPERABLE and adjusted to the proper value.The Low Power Reactor Trips Block, P-7 interlock, is actuated from either the Power Range Neutron Flux, P-10, or the Turbine Impulse Chamber Pressure, P-13 interlock.
The P-7 interlock is a logic Function with train, not channel identity.A COT is performed prior to initiation of the PHYSICS TESTS.This will ensure that the RTS is properly aligned to provide the required degree of core protection during the performance of the PHYSICS TESTS.A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable COT of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
The SR 3.3.1.8 Frequency is sufficient for the power range and intermediate range neutron detectors to ensure that the instrumentation is OPERABLE before initiating PHYSICS TESTS.SR 3.4.19.3 The Low Power Reactor Trips Block, P-7 interlock, must be verified to be OPERABLE in MODE 1 by LCO 3.3.1,"Reactor Trip System Instrumentation." The P-7 interlock is actuated from either the Power Range Neutron Flux, P-10, or the Turbine Impulse Chamber Pressure, P-13 interlock.
The P-7 interlock is a logic Function.An ACTUATION LOGIC TEST is performed to verify OPERABILITY of the P-7 interlock prior to initiation of startup and PHYSICS TESTS.This will ensure that the RTS is properly functioning to provide the required degree of core protection during the performance of the PHYSICS TESTS.WOG STS B 3.4.19-3 Rev.3.0, 03/31/04 Accumulators B 3.5.1 BASES .- ACTIONS (continued) If more than one accumulator is inoperable, the plant is in a condition outside the accident analyses; therefore, LC0 3.0.3 must be entered immediately.
SURVEILLANCE SR 3.5.1 .I REQUIREMENTS Each accumulator valve should be verified to be fully ope- fm3. This verification ensures that the accumulators are available for injection and ensures timely discovery if a valve should be less than fully open. If an isolation valve is not fully open, the rate of injection to the RCS would be reduced. Although a motor operated valve position should not change with power removed, a close could result in not meeting accident analyses assumptions.
.@ requency,$considered reasonable in view of other administrative controls that ensure- mispositioned isolation valve is unlikely.
+ enziT;;fn 6&Zz5~ SR 3.5.1.2 and SR 3.5.1.3 Qved 124'!io&$orated wate nitrogen cover pressure are verified for each accumulator.
ncycufiicient to ensure -3 adequate injection during a LOCA. Because of e static design of the accumulator, a 12 hour Frequency usually allows the operatorto identify changes before limits are reached. Operating experience has shown this Frequency to be appropriate for early detection and correction of off normal trends.--
sea The boron concentration should be verified to be within required limits for each accumulato~~~since the static design of the accumulators limits the ways in which the concentration can be changed. Bhe 31 day Frequency is adequate to identify changes that could occur from mechanisms such as stratification or inleakage@amplinq the affected accumulator within 6 hours after a 1% volume increase will identify whether inleakage has caused a reduction in boron concentration to below the required limit. It is not necessary to verify boron concentration if the added water inventory is from the refueling water storage tank (RWST), because the water contained in the RWST is within the accumulator boron concentration requirements. This is consistent with the recommendation of NUREG-I 366 (Ref. 5). WOG STS B 3.5.1-6 Rev. 3.0, 03/31/04 Accumulators B 3.5.1 BASES ACTIONS (continued)
If more than one accumulator is inoperable, the plant is in a condition outside the accident analyses;therefore, LCO 3.0.3 must be entered immediately.
SR 3.5.1.2 and SR 3.5.1.3 SURVEILLANCE REQUIREMENTS SR 3.5.1.1 Each accumulator valve should be verified to be fully<!$..tl@.This verification ensures that the accumulators are available for injection and ensures timely discovery if a valve should be less than fully open.If an isolation valve is not fully open, the rate of injection to the RCS would be reduced.Although a motor operated valve position should not change with power removed, a closed valv could result in not..ff....A0 meeting accident analyses assumptions.
reasonable in view of other administrative controls that ensure a mispositioned isolation valve is unlikely.--,.-, ,A.J Ilh',<Eveld 12"BQu[i)$orated water and nitrogen cover pressure arer\verified for each accumulator.
sufficient to ens re ot adequate injection during a LOCA.Because anne static design of the accumulator, a 12 hour Frequency usually allows the operator to identify changes before limits are reached.Operating experience has shown this Frequency to be appropriate for early detection and correction of off normalSR 3.5.1.4 The boron concentration should be verified to be within required limits for each the static design of the accumulators limits the ways in which the concentration can be changed.Uhe 31 day Frequency is adequate 10 identify changes that could occur 1: from mechanisms such as stratification or inleakagettSampling the-rl affected accumulator within 6 hours after a 1%volume Increase will identify whether inleakage has caused a reduction in boron concentration to below the required limit.It is not necessary to verify boron concentration if the added water inventory is from the refueling water storage tank (RWST), because the water contained in the RWST is within the accumulator boron concentration requirements.
This is consistent with the recommendation of NUREG-1366 (Ref.5).WOGSTS B 3.5.1-6 Rev.3.0, 03/31/04 Accumulators B 3.5.1 BASES -- - - SURVEILLANCE REQUIREMENTS (continued)
~erification@~~&that power is removed from each accumulator isolation valve operator when the RCS pressure is 2 [2000] psig ensures that an active failure could not result in the undetected closure of an accumulator motor operated isolation valve.
If this were to occur, only two accumulators would be available for injection given a single failure coincident with a LOCA.@~~C~
power is removed under administrative control. the 31 dav Freouencv will arovide adeauate assurance that This SR allows power to be supplied to the motor operated isolation valves when RCS pressure is < 2000 psig, thus allowing operational flexibility by avoiding unnecessary delays to manipulate the breakers during plant startups or shutdowns.
REFERENCES
: 1. FSAR, Chapter [6]. 2. 10 CFR 50.46. 3. FSAR, Chapter
[15]. 4. WCAP-15049-A, Rev.
1, April 1999.
: 5. NUREG-1 366, February 1990. WOG STS Rev. 3.0, 03/31/04 Accumulators B 3.5.1 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.5.1.5 power is removed from each accumulator isolation valve operator when the RCS pressure is[2000]psig ensures that an active failure could not result in the undetected closure of an accumulator motor operated isolation valve.If this were to occur, only two accumulators would be available for injection given a single failure coincident with a power is removed under administrative control, the 31 day Frequency will provide adequate assurance that power is removed.
This SR allows power to be supplied to the motor operated isolation valves when ReS pressure is<2000 psig, thus allowing operational flexibility by avoiding unnecessary delays to manipulate the breakers during plant startups or shutdowns.
REFERENCES 1.FSAR, Chapter[6J.2.10 CFR 50.46.3.FSAR, Chapter[15].4.WCAP-15049-A, Rev.1, April 1999.5.NUREG-1366, February 1990.WOGSTS B 3.5.1-7 Rev.3.0, 03/31/04 ECCS - Operating B 3.5.2 BASES ACTIONS (continued)
Reference 6 describes situations in which one component, such as an RHR crossover valve, can disable both ECCS trains. With one or more component(s) inoperable such that 100% of the flow equivalent to a single OPERABLE ECCS train is not available, the facility is in a condition outside the accident analysis. Therefore, LC0 3.0.3 must be immediately entered. 6.1 and 8.2 If the inoperable trains cannot be returned to OPERABLE status within the associated Completion Time, the plant must be brought to a MODE in which the LC0 does not apply. To achieve this status, the plant must be brought to MODE 3 within 6 hours and MODE 4 within 12 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.
Condition A is applicable with one or more trains inoperable. The allowed Completion Time is based on the assumption that at least 100%
of the ECCS flow equivalent to a single OPERABLE ECCS train is available. With less than 100% of the ECCS flow equivalent to a single OPERABLE ECCS train available, the facility is in a condition outside of the accident analyses. Therefore, LC0 3.0.3 must be entered immediately.
SURVEILLANCE SR 3.5.2.1 REQUIREMENTS Verification of proper valve position ensures that the flow path from the ECCS pumps to the RCS is maintained. Misalignment of these valves could render both ECCS trains inoperable. Securing these valves in position by removal of power or by key locking the control in the correct position ensures that they cannot change position as a result of an active failure or be inadvertently misaligned. These valves are of the type, described in Reference 6, that can disable th function of both ECCS trains and invalidate the accident analyses.
6 12 hour Frequency is considered reasonable in view of other admrnistrative controls that will ensure a mispositioned valve is unlikely.
WOG STS B 3.5.2-7 Rev. 3.1, 12/01/05 ECCS-Operating B 3.5.2 BASES ACTIONS (continued)
Reference 6 describes situations in which one component, such as an RHR crossover valve, can disable both ECCS trains.With one or more component(s) inoperable such that 100%of the flow equivalent to a single OPERABLE ECCS train is not available, the facility is in a condition outside the accident analysis.Therefore, LCO 3.0.3 must be immediately entered.B.1 and B.2 If the inoperable trains cannot be returned to OPERABLE status within the associated Completion Time, the plant must be brought to a MODE in which the LCO does not apply.To achieve this status, the plant must be brought to MODE 3 within 6 hours and MODE 4 within 12 hours.The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.Condition A is applicable with one or more trains inoperable.
The allowed Completion Time is based on the assumption that at least 100%of the ECCS flow equivalent to a single OPERABLE ECCS train is available.
With less than 100%of the ECCS flow equivalent to a single OPERABLE ECCS train available, the facility is in a condition outside of the accident analyses.Therefore, LCO 3.0.3 must be entered immediately.
SURVEILLANCE REQUIREMENTS SR 3.5.2.1 Verification of proper valve position ensures that the flow path from the ECCS pumps to the RCS is maintained.
Misalignment of these valves could render both ECCS trains inoperable.
Securing these valves in position by removal of power or by key locking the control in the correct position ensures that they cannot change position as a result of an active failure or be inadvertently misaligned.
These valves are of the type, described in Reference 6, that can disablefunction of both ECCS trains and invalidate the accident analyses.!!'
12 hour Frequency is considered reasonable in view of other administrative controls that will ensure a mispositioned valve is unlikely...
WOGSTS Rev.3.1,12/01/05 BASES ECCS - Operating B 3.5.2 SURVEILLANCE REQUIREMENTS (continued) Verifying the correct alignment for manual, power operated, and automatic valves in the ECCS flow paths provides assurance that the proper flow paths will exist for ECCS operation. This SR does not apply to valves that are locked, sealed, or otherwise secured in position, since these were verified to be in the correct position prior to locking, sealing, or securing.
A valve that receives an actuation signal is allowed to be in a nonaccident position provided the valve will automatically reposition within the proper stroke time. This Surveillance does not require any testing or valve manipulation. Rather, it involves verification that th se valves capable of being mispositioned are in the correct position. The 31 day Frequency is appropriate because the valves are operate c under administrative control, and an improper valve position would only affect a single train. This Freauencv has been shown-to be acceptable through - operating experience.'+-, With the exception of the operating centrifugal charging pump, the ECCS pumps are normally in a standby, nonoperating mode.
As such, flow path piping has the potential to develop voids and pockets of entrained gases. Maintaining the piping from the ECCS pumps to the RCS full of water ensures that the system will perform properly, injecting its full capacity into the RCS upon demand. This will also prevent water hammer, pump cavitation, and pumping of noncondensible gas (e.g., air, nitrogen, or hydrogen) into the r actor vessel following an SI signal or during shutdown cooling. the 31 day Frequency takes into consideration the gradual nature of gas accumulation in the ECCS piping and the procedural controls governing system operation. Periodic surveillance testing of ECCS pumps to detect gross degradation caused by impeller structural damage or other hydraulic component problems is required by the ASME Code. This type of testing may be accomplished by measuring the pump developed head at only one point of the pump characteristic curve.
This verifies both that the measured performance is within an acceptable tolerance of the original pump baseline performance and that the performance at the test flow is greater than or equal to the performance assumed in the plant safety analysis.
SRs are specified in the lnservice Testing Program of the ASME Code. The ASME Code provides the activities and Frequencies necessary to satisfy the requirements.
WOG STS B 3.5.2-8 Rev. 3.1, 12/01/05 ECCS w Operating B 3.5.2 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.5.2.2 Verifying the correct alignment for manual, power operated, and automatic valves in the ECCS flow paths provides assurance that the proper flow paths will exist for ECCS operation.
This SR does not apply to valves that are locked, sealed, or otherwise secured in position, since these were verified to be in the correct position prior to locking, sealing, or securing.A valve that receives an actuation signal is allowed to be in a nonaccident position provided the valve will automatically reposition within the proper stroke time.This Surveillance does not require any testing or valve manipulation.
Rather, it involves verification se valves capable of being mispositioned are in the correct position.The 31 day Frequency is appropriate because the valves are operate under administrative control, and an improper valve position would only affect a single train.This Frequency has been shown to be acceptable through operating experience.
SR 3.5.2.3 With the exception of the operating centrifugal charging pump, the ECCS pumps are normally in a standby, nonoperating mode.As such, flow path piping has the potential to develop voids and pockets of entrained gases.Maintaining the piping from the EGCS pumps to the RCS full of water ensures that the system will perform properly, injecting its full capacity into the RCS upon demand.This will also prevent water hammer, pump cavitation, and pumping of noncondensible gas (e.g., air, nitrogen, or hydrogen)into the vessel following an SI signal or during shutdown cooling.l!.he 31 day Frequency takes into consideration the gradual nature of gas accumulation in the ECCS piping and the procedural controls governing system operation.
SR 3.5.2.4 Periodic surveillance testing of EGGS pumps to detect gross degradation caused by impeller structural damage or other hydraulic component problems is required by the ASME Code.This type of testing may be accomplished by measuring the pump developed head at only one point of the pump characteristic curve.This verifies both that the measured performance is within an acceptable tolerance of the original pump baseline performance and that the performance at the test flow is greater than or equal to the performance assumed in the plant safety analysis.SRs are specified in the Inservice Testing Program of the ASME Code.The ASME Code provides the activities and Frequencies necessary to satisfy the requirements.
-WOG STS B 3.5.2-8 Rev.3.1, 12/01/05 ECCS - Operating B 3.5.2 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.5.2.5 and SR 3.5.2.6 These Surveillances demonstrate that each automatic ECCS valve actuates to the required position on an actual or simulated SI signal and that each ECCS pump starts on receipt of an actual or simulated SI signal. This Surveillance is not required for valves that are locked, sealed, or otherwise secured in the required position under administrative controls.Ehe 18 month Frequency is based on the need to perform these Surveillances under the conditions that apply during a plant outage and the potential for unplanned plant transients if the Surveillances were performed with the reactor at power. The 18 month Frequency is also acceptable based on consideration of the design reliability (and confirming operating experience) of the equipment. The actuation logic is tested as part of ESF Actuation System testing, and equipment performance is monitored as part of the lnservice Testing P SR 3.5.2.7 Realignment of valves in the flow path on an S1 signal is necessary for proper ECCS performance. These valves have stops to allow proper positioning for restricted flow to a ruptured cold leg, ensuring that the other cold legs receive at least the required minimum flow. Surveillance is not required for plants with flow limiting 18 month Frequency is based on the same reasons as Periodic inspections of the containment sump suction inlet ensure that it is unrestricted and stays in proper operating condition. The 18 month Frequency is based on the need to perform this Survei F ance under the conditions that appl) during a plant outage, on the need to have access to the location, and because of the potential for an unplanned transient if the Surveillance were performed with the reactor at power. This Frequency has been found to be sufficient to detect abnormal degradation and is - confirmed by operating experience.
WOG STS B 3.5.2-9 Rev. 3.1. 12/01/05 ECCS*Operating B 3.5.2 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.5.2.5 and SR 3.5.2.6 These Surveillances demonstrate that each automatic ECCS valve actuates to the required position on an actual or simulated SI signal and that each ECCS pump starts on receipt of an actual or simulated SI signal.This Surveillance is not required for valves that are locked, sealed, or otherwise secured in the required position under administrative controls.{!he 18 month Frequency is based on the need to perform these Surveillances under the conditions that apply during a plant outage and the potential for unplanned plant transients if the Surveillances were performed with the reactor at power.The 18 month Frequency is also acceptable based on consideration of the design reliability (and confirming operating experience) of the equipment.
The actuation logic is tested as part of ESF Actuation System testing, and equipment performance is monitored as part of the Inservice Testing Pro:;g:;.;ra;;;.;m..;.;.;....
:I'.r,Ser SR 3.5.2.7 Realignment of valves in the flow path on an SI signal is necessary for proper ECCS performance.
These valves have stops to allow proper positioning for restricted flow to a ruptured cold leg, ensuring that the other cold legs receive at least the required minimum flow.This Surveillance is not required for plants with flow limiting orifices.f'The 18 month Frequency is based on the same reasons as those in SR 3.5.2.5 and SR 3.5.2.6.</"".'."""'''-''.'''''''.''.''''''.
*,""t*.........,".'''',.'4'I: ,2J
.....SR 3.5.2.8 Periodic inspections of the containment sump suction inlet ensure that it isunrestrictedand stays in proper operating condition.
rfhe 18 month Frequency is based on the need to perform this Surveitrance under the conditions that apply during a plant outage, on the need to have access to the location, and because of the potential for an unplanned transient if the Surveillance were performed with the reactor at power.This Frequency has been found to be sufficient to detect abnormal degradation and is confirmed by operating experience.__
I\.
r'*,t*'?.I'nrJ\WOGSTS B 3.5.2-9 Rev.3.1.12/01/05 RWST B 3.5.4 BASES -- ACTIONS (continued) With the RWST inoperable for reasons other than Condition A (e.g., water volume), it must be restored to OPERABLE status within 1 hour. In this Condition, neither the ECCS nor the Containment Spray System can perform its design function. Therefore, prompt action must be taken to restore the tank to OPERABLE status or to place the plant in a MODE in which the RWST is not required. The short time limit of 1 hour to restore the RWST to OPERABLE status is based on this condition simultaneously affecting redundant trains.
C.1 and C.2 If the RWST cannot be returned to OPERABLE status within the associated Completion Time, the plant must be brought to a MODE in which the LC0 does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 5 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems. SURVEILLANCE SR 3.5.4.1 REQUIREMENTS The RWST borated water temperature should be verified to be within the limits assumed in the accident analyses Frequencbis sufficient to identify a temperature change 6~ Lq how$ approach either limit and has been shown to be acceptable through operating experience.
~7-X) The SR is modified by a Note that eliminates the requirement to perform this Surveillance when ambient air temperatures are within the operating limits of the RWST. With ambient air temperatures within the band, the RWST temperature should not exceed the limits.
WOG STS B 3.5.4-5 Rev. 3.0, 03/31/04 RWST B 3.5.4 BASES ACTIONS (continued)
With the RWST inoperable for reasons other than Condition A (e.g., water volume), it must be restored to OPERABLE status within 1 hour.In this Condition, neither the ECCS nor the Containment Spray System can perform its design function.Therefore, prompt action must be taken to restore the tank to OPERABLE status or to place the plant in a MODE in which the RWST is not required.The short time limit of 1 hour to restore the RWST to OPERABLE status is based on this condition simultaneously affecting redundant trains.C.1 and C.2 If the RWST cannot be returned to OPERABLE status within the associated Completion Time, the plant must be brought to a MODE in which the LCO does not apply.To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 5 within 36 hours.The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.SURVEILLANCE REQUIREMENTS SR 3.5.4.1 The RWST borated water temperature should be verified ver to be within the limits assumed in the accident analyses Frequenc,bis sufficient to identify a temperature change that would approach either limit and has been shown to be acceptable through operating ex p erience*<-(If\3,?
....+3)The SR is modified by a Note that eliminates the requirement to perform this Surveillance when ambient air temperatures are within the operating limits of the RWST.With ambient air temperatures within the band, the RWST temperature should not exceed the limits.WOGSTS B 3.5.4-5 Rev.3.0, 03/31/04 RWST B 3.5.4 BASES SURVEILLANCE REQUIREMENTS (continued)
The RWST water volume should be verified@s&to be above the required minimum level in order to ensure that a sufficient initial supply is available for injection and to support continued ECCS and Containment Spray System pump operation on recirculation.
ante the RWST volume is normally stable and is protected by an alarm, a 7 day Frequency is appropriate and has been shown to be acceptable through operating experience.
4-,r.---.-- - -- - .I -- 1-cj e utt8 The boron concentration of the RWST should be verifiedkx&to be within the required limits.
This SR ensures that the reactor will remain subcritical following a LOCA. Further, it assures that the resulting sump pH will be maintained in an acceptable range so that boron precipitation in the core will not occur and the effect of chloride and caustic stress rrosion on mechanical systems and components will be minimized. Since the RWST volume is normally stable, a 7 day sampling Frequency to verify boron concentration is appropriate and has been shown to be acceptable through operating experience.
k- REFERENCES
: 1. FSAR, Chapter [6] and Chapter [15]. WOG STS Rev. 3.0, 03/31/04 RWST B 3.5.4 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.5.4.2 The RWST water volume should be verified<[ver<
h'iiiYSlto be above the required minimum level in order to ensure that a sufficient initial supply is available for injection and to support continued ECCS and Containment Spray System pump operation on recirculation.
[&sect;jnce the RWST volume is normally stable and is protected by an alarm, a 7 day Frequency is appropriate and has been shown to be acceptable through operating experience.
__.-
REFERENCES SR 3.5.4.3 The boron concentration of the RWST should be verified (8;dY" 7to be within the required limits.This SR ensures that the reactor will remain subcritical following a LOCA.Further, it assures that the resulting sump pH will be maintained in an acceptable range so that boron precipitation in the core will not occur and the effect of chloride and caustic stress on mechanical systems and components will be minimized.
L&sect;ince the RWST volume is normally stable, a 7 day sampling Frequency to verify boron concentration is appropriate and has been shown to be acceptable through operating experience.WOGSTS B 3.5.4-6 Rev.3.0, 03/31/04 Seal Injection Flow B 3.5.5 BASES ACTIONS A.1 With the seal injection flow [resistance]
not within its limit, the amount of charging flow available to the RCS may be reduced. Under this Condition, action must be taken to restore the flow [resistance]
to within its limit.
The operator has 4 hours from the time the flow [resistance] is known to not be within the limit to correctly position the manual valves and thus be in compliance with the accident analysis.
The Completion Time minimizes the potential exposure of the plant to a LOCA with insufficient injection flow and provides a reasonable time to restore seal injection flow [resistance] within limits.
This time is conservative with respect to the Completion Times of other ECCS LCOs; it is based on operating experience and is sufficient for taking corrective actions by operations personnel.
B.l and B.2 When the Required Actions cannot be completed within the required Completion Time, a controlled shutdown must be initiated. The Completion Time of 6 hours for reaching MODE 3 from MODE I is a reasonable time for a controlled shutdown, based on operating experience and normal cooldown rates, and does not challenge plant safety systems or operators. Continuing the plant shutdown begun in Required Action B.1, an additional 6 hours is a reasonable time, based on operating experience and normal cooldown rates, to reach MODE 4, where this LC0 is no longer applicable. SURVEILLANCE SR 3.5.5.1 REQUIREMENTS Verificatione-mgthat the manual seal injection throttle valves are adjusted to give a flow [resistance]
within the limit ensures that the ECCS injection flows stay within the safety analysis.
A differential pressure is established between the charging header and the RCS, and the total seal injection flow is verified to within the limit determined in accordance with the ECCS safety analysis. [The flow [resistance] shall be verified by confirming seal injection flow 5 [40] gpm with the RCS at normal operating pressure, the charging flow control valve full open, and the charging header pressure 2 [2480]. The flow [resistance] shall be verified by confirming seal injection flow and differential pressure within the acceptable region of Figure 3.5.5-1. WOG STS Rev. 3.0, 03/31/04 BASES ACTIONS SURVEILLANCE REQUIREMENTS Seal Injection Flow B 3.5.5 With the seal injection flow[resistance]
not within its limit, the amount of charging flow available to the RCS may be reduced.Under this Condition, action must be taken to restore the flow[resistance]
to within its limit.The operator has 4 hours from the time the flow[resistance]
is known to not be within the limit to correctly position the manual valves and thus be in compliance with the accident analysis.The Completion Time minimizes the potential exposure of the plant to a LOCA with insufficient injection flow and provides a reasonable time to restore seal injection flow[resistance]
within limits.This time is conservative with respect to the Completion Times of other ECCS LCOs;it is based on operating experience and is sufficient for taking corrective actions by operations personnel.
B.1 and B.2 When the Required Actions cannot be completed within the required Completion Time, a controlled shutdown must be initiated.
The Completion Time of 6 hours for reaching MODE 3 from MODE 1 is a reasonable time for a controlled shutdown, based on operating experience and normal cooldown rates, and does not challenge plant safety systems or operators.
Continuing the plant shutdown begun in Required Action 8.1, an additional 6 hours is a reasonable time, based on operating experience and normal cooldown rates, to reach MODE 4, where this LCO is no longer applicable.
SR 3.5.5.1 Verification(fve@111ay&sect;>that the manual seal injection throttle valves are adjusted to give a flow[resistance]
within the limit ensures that the ECCS injection flows stay within the safety analysis.A differential pressure is established between the charging header and the RCS, and the total seal injection flow is verified to within the limit determined in accordance with the ECCS safety analysis.[The flow[resistance]
shall be verified by confirming seal injection flow[40]gpm with the RCS at normal operating pressure, the charging flow control valve full open, and the charging header pressure[2480].OR The flow[resistance]
shall be verified by confirming seal injection flow and differential pressure within the acceptable region of Figure 3.5.5-1.WOG STS B 3.5.5-4 Rev.3.0, 03/31/04 Seal Injection Flow B 3.5.5 BASES SURVEILLANCE REQUIREMENTS (continued)
The flow resistance shall be 2 [0.2117] ftlgpm2.]
Control valves in the flow path between the charging header and the RCS pressure sensing points must be in their post accident position (e.g., charging flow control valve open) during this Surveillance to correlate with the acceptance criteria.
Ehe Frequency of 31 days is based on engineering judgment and is consistent with other ECCS valve Surveillance Frequencies.
The Frequency has proven to be acceptable through operating experience.
As noted, the Surveillance is not required to be performed until 4 hours after the RCS pressure has stabilized within a + 20 psig range of normal operating pressure. The RCS pressure requirement is specified since this configuration will produce the required pressure conditions necessary to assure that the manual valves are set correctly. The exception is limited to 4 hours to ensure that the Surveillance is timely. REFERENCES
: 1. FSAR, Chapter [6] and Chapter
[I 51. 2. 10 CFR 50.46. WOG STS Rev. 3.0, 03/31/04 Seal Injection Flow B 3.5.5 BASES SURVEILLANCE REQUIREMENTS (continued)
OR The flow resistance shall be;?:[0.2117]ft/gpm 2.]Control valves in the flow path between the charging header and the RCS pressure sensing points must be in their post accident position (e.g.*charging flow control valve open)during this Surveillance tocorrelatewith the acceptance criteria.(fhe Frequency of 31 days is based on engineering jUdgment and is<:J!'Se L?)consistent with other ECCS valve Surveillance Frequencies.
The r Frequency has proven to be acceptable through operating experience.
As noted.the Surveillance is not required to be performed until 4 hours after the RCS pressure has stabilized within a+/-20 psig range of normal operating pressure.The ReS pressure requirement is specified since this configuration will produce the required pressure conditions necessary to assure that the manual valves are set correctly.
The exception is limited to 4 hours to ensure that the Surveillance is timely.REFERENCES 1.FSAR, Chapter[6]and Chapter[15].2.10 CFR 50.46.WOGSTS B 3.5.5-5 Rev.3.0, 03/31/04 BIT B 3.5.6 BASES ACTIONS (continued) After determining that the BIT is inoperable and the Required Actions of B.1 and B.2 have been completed, the tank must be returned to OPERABLE status within 7 days. These actions ensure that the plant will not be operated with an inoperable BIT for a lengthy period of time. It should be noted, however, that changes to applicable MODES cannot be made until the BIT is restored to OPERABLE status pursuant to the provisions of LC0 3.0.4. Even though the RCS has been borated to a safe and stable condition as a result of Required Action B.2, either the BIT must be restored to OPERABLE status (Required Action C.l) or the plant must be placed in a condition in which the BIT is not required (MODE 4). The 12 hour Completion Time to reach MODE 4 is reasonable, based on operating experience and normal cooldown rates, and does not challenge plant safety systems or operators. SURVEILLANCE SR 3.5.6.1 REQUIREMENTS verification-hat the temperature is at or above the specified minimum temperature identify a temperature change that would approach the acceptable limit.
The solution temperature is also monitored by an alarm that provides fur%/ assurance of protection against low temperature.~~requency~as been shown to be acceptable through operating experience.
Verification -that the BIT contained volume is above the C required limitb frdnt en&h to)assure that this volume will be available for quick injection into the RCS. If the volume is too low, the BIT would not provide enough borated water to ensure subcriticality during recirculation or to shut down the core following an MSLB. rnce the BIT volume is normally stable, a 7 day Frequency is appropriate and has been shown to be acceptable through operating experience.
&;-&xi) WOG STS B 3.5.6-4 Rev. 3.0, 03/31/04 BIT B 3.5.6 BASES ACTIONS (continued)
After determining that the BIT is inoperable and the Required Actions of B.1 and B.2 have been completed, the tank must be returned to OPERABLE status within 7 days.These actions ensure that the plant will not be operated with an inoperable BIT for a lengthy period of time.It should be noted, however, that changes to applicable MODES cannot be made until the BIT is restored to OPERABLE status pursuant to the provisions of LCO 3.0.4.Even though the RCS has been borated to a safe and stable condition as a result of Required Action B.2, either the BIT must be restored to OPERABLE status (Required Action C.1)or the plant must be placed in a condition in which the BIT is not required (MODE 4).The 12 hour Completion Time to reach MODE 4 is reasonable, based on operating experience and normal cool down rates, and does not challenge plant safety systems or operators.
SR 3.5.6.2 SURVEILLANCE REQUIREMENTS SR 3.561 f ZHVerification*ert24lfjouthat the BIT ater temperature is at or above the specified minimum temperature 6
identify a temperature change that would approach the acceptable limit.The solution temperature is also monitored by an alarm that provides assurance of protection against low temperature.a
.requency'1\asbeen shown to be acceptable through operatingy')Verification a that the volume is above the required limit fro ent en h to assure that this volume will be available for quick injection into the RCS.If the volume is too low, the BIT would not provide enough borated water to ensure subcriticality during recirculation or to shut down the core following an MSLB.@nce the BIT volume is normally stable,a7 day Frequency is appropriate and has been shown to be acceptable through operating WOGSTS B 3.5.6-4 Rev.3.0, 03/31/04 BIT B 3.5.6 BASES SURVEILLANCE REQUIREMENTS (continued)
~erificationmF@that the boron concentration of the BIT is within the required band ensures that the reactor remains subcritical following a LOCA; it limits return to power following an MSLB, and maintains the resulting sump pH in an acceptable range so that boron precipitation will not occur in the core. In addition, the effect of chloride and'caustic stress corrosion on mechanical systems and components will be minimized.
The BIT is in a recirculation loop that provides continuous circulation of the boric acid solution through the BIT and the boric acid tank (BAT). There are a number of points along the recirculation loop where local samptes can be taken. The actual location used to take a sample of the solution is specified in the plant Surveillance procedures. Sampling from the BAT to verify the concentration of the BIT is not recommended, since this sample may not be homogenous and the boron concentration of the two tanks may differ. The sample should be taken from the BIT or from a point in the flow path of the BIT recirculation loop. 1. FSAR, Chapter [6] and Chapter
[15]. \ 2. 10 CFR 50.46. WOG STS Rev. 3.0, 03/31/04 BIT B 3.5.6 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.5.6.3 the boron concentration of the BIT is within the required band ensures that the reactor remains subcritical following a LOCA;it limits return to power following an MSLB, and maintains the resulting sump pH in an acceptable range so that boron precipitation will not occur in the core.In addition, the effect of chloride and'caustic stress corrosion on mechanical systems and components will be minimized.
The BIT is in a recirculation loop that provides continuous circulation of the boric acid solution through the BIT and the boric acid tank (BAT).There are a number of points along the recirculation loop where local samples can be taken.The actual location used to take a sample of the solution is specified in the plant Surveillance procedures.
Sampling from the BAT to verify the concentration of the BIT is not recommended, since this sample may not be homogenous and the boron concentration of the two tanks may differ.2.10 CFR 50.46.1.FSAR, Chapter[6]and Chapter[15].REFERENCES The sample should be taken from the BIT or from a point in the flow path_-----:)of the BIT recirculation loop.WOG STS Rev.3.0, 03/31/04 Containment Air Locks (Atmospheric, Subatmospheric, Ice Condenser, and Dual)
B 3.6.2 BASES SURVEILLANCE SR 3.6.2.1 REQUIREMENTS Maintaining containment air locks OPERABLE requires compliance with the leakage rate test requirements of the Containment Leakage Rate Testing Program. This SR reflects the leakage rate testing requirements with regard to air lock leakage (Type B leakage tests). The acceptance criteria were established during initial air lock and containment OPERABILITY testing.
The periodic testing requirements verify that the air lock leakage does not exceed the allowed fraction of the overall containment leakage rate.
The Frequency is required by the Containment Leakage Rate Testing Program.
The SR has been modified by two Notes. Note 1 states that an inoperable air lock door does not invalidate the previous successful performance of the overall air lock leakage test. This is considered reasonable since either air lock door is capable of providing a fission product barrier in the event of a DBA. Note 2 has been added to this SR requiring the results to be evaluated against the acceptance criteria which
 
is applicable to SR 3.6.1 .I. This ensures that air lock leakage is properly accounted for in determining the combined Type B and C containment leakage rate.
[SR 3.6.2.2 The air lock interlock is designed to prevent simultaneous opening of both doors in a single air lock. Since both the inner and outer doors of an air lock are designed to withstand the maximum expected post accident containment pressure, closure of either door will support containment OPERABILITY. Thus, the door interlock feature supports containment OPERABILITY while the air lock is being used for personnel transit in and out of the containment. Periodic testing of this interlock demonstrates that the interlock will function as designed and that simultaneous opening of the inner and outer doors will not inadvertently occur. Due to the purely mechanical nature of this interlock, and given tha & t e interlock mechanism is not normally challenged when the containment air lock door is used for entry and exit (procedures require strict adherence to single door op-ening), this test is only required to be performed every 24 months. The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage, and the potential for loss of containment OPERABILITY if the Surveillance were performed with the reactor at power. The 24 month Frequency for the interlock is justified based on generic operating experience. The 24 month Frequency is based on engineering judgment and is considered adequate given that the interlock is not challenged during the use of the airlock. 4- yziE) WOG STS B 3.6.2-6 Rev. 3.0, 03/31/04 BASES Containment Air Locks (Atmospheric, Subatmospheric, Ice Condenser, and Dual)B 3.6.2 SURVEILLANCE REQUIREMENTS SR 3.6.2.1 Maintaining containment air locks OPERABLE requires compliance with the leakage rate test requirements of the Containment Leakage Rate Testing Program.This SR reflects the leakage rate testing requirements with regard to air lock leakage (Type B leakage tests).The acceptance criteria were established during initial air lock and containment OPERABILITY testing.The periodic testing requirements verify that the air lock leakage does not exceed the allowed fraction of the overall containment leakage rate.The Frequency is required by the Containment Leakage Rate Testing Program.The SR has been modified by two Notes.Note 1 states that an inoperable air lock door does not invalidate the previous successful performance of the overall air lock leakage test.This is considered reasonable since either air lock door is capable of providing a fission product barrier in the event of a DBA.Note 2 has been added to this SR requiring the results to be evaluated against the acceptance criteria which is applicable to SR 3.6.1.1.This ensures that air lock leakage is properly accounted for in determining the combined Type Band C containment leakage rate.[SR 3.6.2.2 The air lock interlock is designed to prevent simultaneous opening of both doors in a single air lock.Since both the inner and outer doors of an air lock are designed to withstand the maximum expected post accident containmentpressure,closure of either door will support containment OPERABILITY.
Thus, the door interlock feature supports containment OPERABILITY while the air lock is being used for personnel transit in and out of the containment.
Periodic testing of this interlock demonstrates that the interlock will function as designed and that simultaneous opening of the inner and outer doors will not inadvertently occur. to the purely mechanical nature of this interlock, and given thahFie interlock mechanism is not normally challenged when the containment air lock door is used for entry and exit (procedures require strict adherence to single door op_ening), this test is only required to be performed every 24 months.The 24 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage, and the potential for loss of containment OPERABILITY if the Surveillance were performed with the reactor at power.The 24 month Frequency for the interlock is justified based on generic operating experience.
The 24 month Frequency is based on engineering judgment and is considered adequate given that the interlock is not challenged during the use of the airlock.
2)WOGSTS B 3.6.2-6 Rev.3.0, 03/31/04 Containment Isolation Valves (Atmosperic, Subatmospheric, Ice Condenser, and Dual) B 3.6.3 BASES ACTIONS (continued) For the containment purge valve with resilient seal that is isolated in accordance with Required Action E.l, SR 3.6.3.7 must be performed at least once every
[92] days. This assures that degradation of the resilient seal is detected and confirms that the leakage rate of the containment purge valve does not increase during the time the penetration is isolated. The normal Frequency for SR 3.6.3.7, 184 days, is based on an NRC initiative, Generic Issue 8-20 (Ref. 4). Since more reliance is placed on a single valve while in this Condition, it is prudent to perform the SR more often. Therefore, a Frequency of once per 1921 days was chosen and has been shown to be acceptable based on operating experience. Required Action E.2 is modified by two Notes. Note I applies to isolation devices located in high radiation areas and allows these devices to be verified closed by use of administrative means. Allowing verification by administrative means is considered acceptable, since access to these areas is typically restricted. Note 2 applies to isolation devices that are locked, sealed, or otherwise secured in position and allows these devices to be verified closed by use of administrative means. Allowing verification by administrative means is considered acceptable, since the function of locking, sealing, or securing components is to ensure that these devices are not inadvertently repositioned.
] F.l and F.2 If the Required Actions and associated Completion Times are not met, the plant must be brought to a MODE in which the LC0 does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 5 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.
SURVEILLANCE
[ SR 3.6.3.1 REQUIREMENTS Each [42] inch containment purge valve is required to be verified sealed close~&ayptefVal~ This Surveillance is designed to ensure that a gross breach of containment is not caused by an inadvertent or spurious opening of a containment purge valve. Detailed analysis of the purge valves failed to conclusively demonstrate their ability to close during a LOCA in time to limit offsite doses. Therefore, these valves are required to be in the sealed closed position during MODES I, 2, 3, and 4. A WOG STS B 3.6.3-10 Rev. 3.0, 03/31/04 Containment Isolation Valves (Atmosperic, Subatmospheric, Ice Condenser, and Dual)B 3.6.3 BASES ACTIONS (continued)
For the containment purge valve with resilient seal that is isolated in accordance with Required Action E.1, SR 3.6.3.7 must be performed at least once every[92]days.This assures that degradation of the resilient seal is detected and confirms that the leakage rate of the containment purge valve does not increase during the time the penetration is isolated.The normal Frequency for SR 3.6.3.7, 184 days, is based on an NRC initiative, Generic Issue B-20 (Ref.4).Since more reliance is placed on a single valve while in this Condition, it is prudent to perform the SR more often.Therefore, a Frequency of once per[92]days was chosen and has been shown to be acceptable based on operating experience.
Required Action E.2 is modified by two Notes.Note 1 applies to isolation devices located in high radiation areas and allows these devices to be verified closed by use of administrative means.Allowing verification by administrative means is considered acceptable, since access to these areas is typically restricted.
Note 2 applies to isolation devices that are locked, sealed, or otherwise secured in position and allows these devices to be verified closed by use of administrative means.Allowing verification by administrative means is considered acceptable, since the function of locking, sealing, or securing components is to ensure that these devices are not inadvertently repositioned.
]F.1 and F.2 If the Required Actions and associated Completion Times are not met, the plant must be brought to a MODE in which the LCO does not apply.To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 5 within 36 hours.The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.SURVEILLANCE REQUIREMENTS
[SR 3.6.3.1 Each[42 inch containment purge valve is required to be verified sealed close ay rvals This Surveillance is designed to ensure that a gross breach of containment is not caused by an inadvertent or spurious opening of a containment purge valve.Detailed analysis of the purge valves failed to conclusively demonstrate their ability to close during a LOCA in time to limit offsite doses.Therefore, these valves are required to be in the sealed closedpositionduring MODES 1, 2, 3, and 4.A WOGSTS B 3.6.3-10 Rev.3.0, 03/31/04 Containment Isolation Valves (Atmosperic, Subatmospheric, Ice Condenser, and Dual)
B 3.6.3 BASES -- SURVEILLANCE REQUIREMENTS (continued) containment purge valve that is sealed closed must have motive power to the valve operator removed. This can be accomplished by de-energizing the source of electric power or by removing the air supply to the valve his application, the term "sealed" has no connotation of leak a result of an NRC initiative, Generic o containment purge valve use during plant operations.
In the event purge valve leakage requires entry into Condition E, the Surveillance permits opening one purge valve in a penetration flow path to perform repairs
] WnzeTp This SR ensures that the minipurge valves are closed as required or, if open, open for an allowable reason.
If a purge valve is open in violation of this SR, the valve is considered inoperable.
If the inoperable valve is not otherwise known to have excessive leakage when closed, it is not considered to have leakage outside of limits. The SR is not required to be met when the minipurge valves are open for the reasons stated. The valves may be opened for pressure control, ALARA or air quality considerations for personnel entry, or for Surveillances that require the valves to be open. The minipurge valves are capable of closing in the environment following a LOCA. erefore, these valves are allowed to be open for limited periods of time. 31 day Frequency is consistent wit other containment isolation valve requirements This SR requires verification that each containment isolation manual valve and blind flange located outside containment and not locked, sealed, or otherwise secured and required to be closed during accident conditions is closed. The SR helps to ensure that post accident leakage of radioactive fluids or gases outside of the containment boundary is within design limits. This SR does not require any testing or valve manipulation. Rather, it involves verification that those containment isolation valves outside containment and capable of being mispositioned are in the correct position.Ence verification of valve position for containment isolation valves outside containment is relatively easy, WOG STS B 3.6.3-1 1 Rev. 3.0, 03/31/04 Containment Isolation Valves (Atmosperic, Subatmospheric, Ice Condenser, and Dual)B 3.6.3 BASES SURVEILLANCE REQUIREMENTS (continued) containment purge valve that is sealed closed must have motive power to the valve operator removed.This can be accomplished by de-energizing the source of electric power or by removing the air supply to the valve operator.In this application, the term"sealed" has no connotation of leak tightness.
The Frequency's a result of an NRC initiative, Generic ssue-e., re a to containment purge valve use during plant operations.
In the event purge valve leakage requires entry into Condition E, the Surveillance permits opening one purge valve in a penetration flow path to perform[SR 3.6.3.2 This SR ensures that the minipurge valves are closed as required or, if open, open for an allowable reason.If a purge valve is open in violation of this SR, the valve is considered inoperable.
If the inoperable valve is not otherwise known to have excessive leakage when closed, it is not considered to have leakage outside of limits.The SR is not required to be met when the minipurge valves are open for the reasons stated.The valves may be opened for pressure control, ALARA or air quality considerations for personnel entry, or for Surveillances that require the valves to be open.The minipurge valves are capable of closing in the environment following a LOCA.JDerefore, these valves are allowed to be open for limited periods of time.LIhe 31 day Frequency is consistent wit other containment isolation valve requirements discussed in SR 3.6.3.3.In.5ert SR 3.6.3.3 This SR requires verification that each containment isolation manual valve and blind flange located outside containment and not locked, sealed, or otherwise secured and required to be closed during accident conditions is closed.The SR helps to ensure that post accident leakage of radioactive fluids or gases outside of the containment boundary is within design limits.This SR does not require any testing or valve manipulation.
Rather, it involves verification that those containment isolation valves outside containment and capable of being mispositioned are in the correct position.(])nce verification of valve position for containment isolation valves outside containment is relatively easy, WOGSTS B 3.6.3-11 Rev.3.0, 03/31/04 Containment Isolation Valves (Atmosperic, Subatmospheric, Ice Condenser, and Dual)
B 3.6.3 BASES SURVEILLANCE REQUIREMENTS (continued) the 31 day Frequency is based on engineering judgment and was chosen to provide added assurance of the correct positions.&'The SR specifies that containment isolation valves that are open under administrative controls are not required to meet the SR during the time the valves are open. This SR does not apply to valves that are locked, sealed, or otherwise secured in the closed position, since these were verified to be in the correct position upon locking, sealing, or securing.
The Note applies to valves and blind flanges located in high radiation areas and allows these devices to be verified closed by use of administrative means. Allowing verification by administrative means is considered acceptable, since access to these areas is typically restricted during MODES I, 2, 3, and 4 for ALARA reasons. Therefore, the probability of misalignment of these containment isolation valves, once they have been verified to be in the proper position, is small.
This SR requires verification that each containment isolation manual valve and blind flange located inside containment and not locked, sealed, or otherwise secured and required to be closed during accident conditions is closed. The SR helps to ensure that post accident leakage of radioactive fluids or gases outside of the containment boundary is within design limits. For containment isolation valves inside containment, the Frequency of "prior to entering MODE 4 from MODE 5 if nat performed within the previous 92 days" is appropriate since these containment isolation valves are operated under administrative controls and the probability of their misalignment is low. The SR specifies that containment isolation valves that are open under administrative controls are not required to meet the SR during the time they are open. This SR does not apply to valves that are locked, sealed, or otherwise secured in the closed position, since these were verified to be in the correct position upon locking, sealing, or securing.
This Note allows valves and blind flanges located in high radiation areas to be verified closed by use of administrative means. Allowing verification by administrative means is considered acceptable, since access to these areas is typically restricted during MODES 1, 2, 3, and 4, for ALARA reasons. Therefore, the probability of misalignment of these containment isolation valves, once they have been verified to be in their proper position, is small. WOG STS B 3.6.3-12 Rev. 3.0, 03/31/04 Containment Isolation Valves (Atmosperic, Subatmospheric, Ice Condenser, and Dual)B 3.6.3 BASES SURVEILLANCE REQUIREMENTS (continued) the 31 day Frequency is based on engineering judgment and was chosen to provide added assurance of the correct positions.
:rhe SR ecifiesthat containment isolation valves that are open under administrative controls are not required to meet the SR during the time the valves are'open.This SR does not apply to valves that are locked, sealed, or otherwise secured in the closed position, since these were verified to be in the correct position upon locking, sealing, or securing.The Note applies to valves and blind flanges located in high radiation areas and allows these devices to be verified closed by use of administrative means.Allowing verification by administrative means is considered acceptable, since access to these areas is typically restricted during MODES 1, 2, 3, and 4 for ALARA reasons.Therefore, the probability of misalignment of these containment isolation valves, once they have been verified to be in the proper position, is small.SR 3.6.3.4 This SR requires verification that each containment isolation manual valve and blind flange located inside containment and not locked, sealed, or otherwise secured and required to be closed during accident conditions is closed.The SR helps to ensure that post accident leakage of radioactive fluids or gases outside of the containment boundary is within design limits.For containment isolation valves inside containment, the Frequency of"prior to entering MODE 4 from MODE 5 if not performed within the previous 92 days" is appropriate since these containment isolation valves are operated under administrative controls and the probability of their misalignment is low.The SR specifies thatcontainmentisolation valves that are open under administrative controls are not required to meet the SR during the time they are open.This SR does not apply to valves that are locked, sealed, or otherwise secured in the closed position, since these were verified to be in the correct position upon locking, sealing, or securing.This Note allows valves and blind flanges located in high radiation areas to be verified closed by use of administrative means.Allowing verification by administrative means is considered acceptable, since access to these areas is typically restricted during MODES 1, 2, 3, and 4, for ALARA reasons.Therefore, the probability of misalignment of these containment isolation valves, once they have been verified to be in their proper position, is small.WOGSTS B 3.6.3-12 Rev.3.0, 03/31/04 Containment Isolation Valves (Atmosperic, Subatmospheric, Ice Condenser, and Dual) B 3.6.3 BASES SURVEILLANCE REQUIREMENTS (continued) Verifying that the isolation time of each automatic power operated containment isolation valve is within limits is required to demonstrate OPERABILITY.
The isolation time test ensures the valve will isolate in a time period less than or equal to that assumed in the safety analyses.
[The isolation time and Frequency of this SR are in accordance with the lnservice Testing Program or 92 days7 [ SR 3.6.3.6 In subatmospheric containments, the check valves that serve a containment isolation function are weight or spring loaded to provide positive closure in the direction of flow. This ensures that these check valves will remain closed when the inside containment atmosphere returns to subatmospheric conditions following a DBA. SR 3.6.3.6 requires verification of he operation of the check valves that are testable during unit operation.
c' The Frequency of 92 days is consistent with the lnservice Testing Program requirement for valve testing on a 92 day For containment purge valves with resilient seals, additional leakage rate testing beyond the test requirements of 10 CFR 50, Appendix J, Option [A][B], is required to ensure OPERABILITY. Operating experience has demonstrated that this type of seal has the potential to degrade in a shorter time period than do other seal types@ased on this observation and the importance of maintaining this penetration leak tight (due to the direct path between containment and the environment), a Frequency of 184 days was established as part of the NRC resolution of Generic Issue B-20, "Containment Leakage Due to Seal Deterioration" (Ref.
Additionally, this SR must be performed within 92 days after opening the valve. The 92 day Frequency was chosen recognizing that cycling the valve could introduce additional seal degradation (beyond that to a valve that has not been opened).
Thus, decreasing the
@T& is a prudent measure after a valve has been opened. 1 WOG STS B 3.6.3-13 Rev. 3.0, 03/31/04 Containment Isolation Valves (Atmosperic, Subatmospheric, Ice Condenser, and Dual)B 3.6.3 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.6.3.5 Verifying that the isolation time of each automatic power operated containment isolation valve is within limits is required to demonstrate OPERABILITY.
The isolation time test ensures the valve will isolate in a time period less than or equal to that assumed in the safety analyses.[The isolation time and Frequency of this SR are in accordance with the InselVice Testing Program or 92
[SR 3.6.3.6 In subatmospheric containments, the check valves that serve a containment isolation function are weight or spring loaded to provide positive closure in the direction of flow.This ensures that these check valves will remain closed when the inside containment atmosphere returns to subatmospheric conditions following a DBA.SR 3.6.3.6 requires verification oL1he oper.ation of the check valves that are testable during unit operation.LThe Frequency of 92 days is consistent with the Inservice Testing Program requirement for valve testing on a 92 day Frequency.
)
t...-.(:"" ,.;',,.,..-.[SR 3.6.3.7 For containment purge valves with resilient seals, additional leakage rate testing beyond the test requirements of 10 CFR 50, Appendix J, Option[A][B), is required to ensure OPERABILITY.
Operating experience has demonstrated that this type of seal has the potential to degrade in a shorter time period than do other seal types.@ased on this observation and the importance of maintaining this penetration leak tight (due to the direct path between containment and the environment), a Frequency of 184 days was established as part of the NRC resolution of Generic Issue B-20,"Containment Leakage Due to Seal Deterioration" (Ref.4 Additionally, this SR must be performed within 92 days after opening the valve.The 92 day Frequency was chosen recognizing that cycling the valve could introduce additional seal degradation (beyond that to a valve that has not been opened).Thus, decreasing the
@&sect;&sect;OW is a prudent measure after a valve has been opened.1 WOGSTS B 3.6.3-13 Rev.3.0, 03/31/04 Containment Isolation Valves (Atmosperic, Subatmospheric, Ice Condenser, and Dual)
B 3.6.3 BASES SURVEILLANCE REQUIREMENTS (continued) Automatic containment isolation valves close on a containment isolation signal to prevent leakage of radioactive material from containment following a DBA. This SR ensures that each automatic containment isolation valve will actuate to its isolation position on a containment isolation signal. This surveillance is not required for valves that are locked, sealed, or otherw' e secured in the required position under administrative controls.
Ge [I81 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power. Operating experience has shown that these components usually pass this Surveillance when performed at the
[I81 month Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.
4 [SR 3.6.3.9 In subatmospheric containments, the check valves that serve a containment isolation function are weight or spring loaded to provide positive closure in the direction of flow. This ensures that these check valves will remain closed when the inside containment atmosphere returns to subatmospheric conditions following a DBA.
SR 3.6.3.9 verifies the operation of the check valves that are not testable during unit operation.
Ehe Frequency of 18 months is based on such factors as the inaccessibility of these valves, the fact that the unit must be shut down to perform the tests, and the successful results of the tests on an 18 month basis during past unit operatio [SR 3.6.3.10 ----------------------------------*
REVIEWER'S NOTE ---- ------- ---- ----------
----------
This SR is only required for those units with resilient seal purge valves allowed to be open during
[MODE 1, 2, 3, or 41 and having blocking devices on the valves that are not permanently installed.
WOG STS B 3.6.3-14 Rev. 3.0. 03131104 Containment Isolation Valves (Atmosperic, Subatmospheric, Ice Condenser, and Dual)B 3.6.3 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.6.3.8 Automatic containment isolation valves close on a containment isolation signal to prevent leakage of radioactive material from containment following a DBA.This SR ensures that each automatic containment isolation valve will actuate to its isolation position on a containment isolation signal.This surveillance is not required for valves that are locked, sealed, or secured in the required position under administrative controls.[18]month Frequency is based on the need to perform this Surveilfance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance wereperformedwith the reactor at power.Operating experience has shown that these components usually pass this Surveillance when performed at the[18]month Frequency.
Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.
[SR 3.6.3.9 In SUbatmospheric containments, the check valves that serve a containment isolation function are weight or spring loaded to provide positive closure in the direction of flow.This ensures that these check valves will remain closed when the inside containment atmosphere returns to subatmospheric conditions following a DBA.SR 3.6.3.9 verifies the operation of the check valves that are not testable during unit operation.l1he Frequency of 18 months is based on such factors as the inaccessibility of these valves, the fact that the unit must be shut down to perform the tests, and the successful results of the tests on an 18 monthbasisduring past unit f2)h5e r[SR 3.6.3.10-----------------------------------REV I EW E R'S NOTE-----------------------------------
This SR is only required for those units with resilient seal purge valves allowed to be open during[MODE 1, 2, 3, or 4]and having blocking devices on the valves that are not permanently installed.
WOGSTS B 3.6.3-14 Rev.3.0, 03/31/04 Containment Isolation Valves (Atmosperic, Subatmospheric, Ice Condenser, and Dual) B 3.6.3 BASES SURVEILLANCE REQUIREMENTS (continued) Verifying that each
[42] inch containment purge valve is blocked to restrict opening to I [50]% is required to ensure that the valves can close under DBA conditions within the times assumed in the analyses of References 1 and 2. If a LOCA occurs, the purge valves must close to maintain containment leakage within the values assumed in the accident analysis. At other times when purge valves are required to be capable of closing (e.g., during movement of [recently] irradiated fuel assemblies), pressurization concerns are not present, thus the purge valves can be fully open.Ehe 18 month Frequency is appropriate because the blocking devices are typically removed only during a refueling outage. ] [ SR 3.6.3.11 This SR ensures that the combined leakage rate of all shield building bypass leakage paths is less than or equal to the specified leakage rate. This provides assurance that the assumptions in the safety analysis are met. The leakage rate of each bypass leakage path is assumed to be the maximum pathway leakage (leakage through the worse of the two isolation valves) unless the penetration is isolated by use of one closed and de-activated automatic valve, closed manual valve, or blind flange.
In this case, the leakage rate of the isolated bypass leakage path is assumed to be the actual pathway leakage through the isolation device. If both isolation valves in the penetration are closed, the actual leakage rate is the lesser leakage rate of the two valves. The Frequency is required by the Containment Leakage Rate Testing Program.
This SR simply imposes additional acceptance criteria. [Bypass leakage is considered part of La. WOG STS B 3.6.3-1 5 Rev. 3.0, 03/31/04 Containment Isolation Valves (Atmosperic, Subatmospheric, Ice Condenser, and Dual)B 3.6.3 BASES SURVEILLANCE REQUIREMENTS (continued)
Verifying that each[42]inch containment purge valve is blocked to restrict opening to S;[50]%is required to ensure that the valves can close under DBA conditions within the times assumed in the analyses of References 1 and 2.If a LOCA occurs, the purge valves must closetomaintain containment leakage within the values assumed in the accident analysis.At other times when purge valves are required to be capable of closing (e.g., during movement of[recently]
irradiated fuel assemblies), pressurization concerns are not present, thus the purge valves can be fully open.Uhe 18 month Frequency is appropriate because the blocking devices are typically removed only during a refueling outage.]1..Q;(\sert6)
[SR 3.6.3.11 This SR ensures that the combined leakage rate of all shield building bypass leakage paths is less than or equal to the specified leakage rate.This provides assurance that the assumptions in the safety analysis are met.The leakage rate of each bypass leakage path is assumed to be the maximum pathway leakage (leakage through the worse of the two isolation valves)unless the penetration is isolated by use of one closed and automatic valve, closed manual valve, or blind flange.In this case, the leakage rate of the isolated bypass leakage path is assumed to be the actual pathway leakage through the isolation device.If both isolation valves in the penetration are closed, the actual leakage rate is the lesser leakage rate of the two valves.The Frequency is required by the Containment Leakage Rate Testing Program.This SR simply imposes additional acceptance criteria.[Bypass leakage is considered part of La.
I EWE R'S NOTE Unless specifically exempted.]
]WOGSTS B 3.6,3-15 Rev, 3.0, 03/31/04 Containment Pressure (Atmospheric, Dual, and Ice Condenser)
B 3.6.4A BASES ACTIONS (continued)
B.l and B.2 If containment pressure cannot be restored to within limits within the required Completion Time, the plant must be brought to a MODE in which the LC0 does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 5 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems. SURVEILLANCE SR 3.6.4A.1 REQUIREMENTS Verifying that containment pressure is within limits ensures that unit o eration remains within the limits assumed in the containment analysis.
The 12 hour Frequency of this SR was developed based on operating e experience related to trending of containment pressure variations during the applicable MODES. Furthermore, the 12 hour Frequency is considered adequate in view of other indications available in the control room, including alarms, to alert the o~erator to an abnormal containment pressure condition.
4----. - -- -iknsd, z3 REFERENCES
: 1. FSAR, Section 16.21. 2. 10 CFR 50, Appendix K. WOG STS Rev. 3.0, 03/31/04 Containment Pressure (Atmospheric, Dual, and Ice Condenser)
B 3.6.4A BASES ACTIONS (continued)
B.1 and B.2 If containment pressure cannot be restored to within limits within the required Completion Time, the plant must be brought to a MODE in which the LCO does not apply.To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 5 within 36 hours.The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.SURVEILLANCE REQUIREMENTS REFERENCES SR 3.6.4A.1 Verifying that containment pressure is within limits ensures that unit..&#xa3;,peration remains within the limits assumed in the containment analysis. 12 hour Frequency of this SR was developed based on operating experience related to trending of containment pressure variations during the applicable MODES.Furthermore, the 12 hour Frequency is considered adequate in view of other indications available in the control room, including alarms, to alert the erator to an abnormal containment pressure condition.
0\-"--,._--
c ert r 1.FSAR, Section[6.2].2.10 CFR 50, Appendix K.WOGSTS B 3.6.4A-3 Rev.3.0, 03/31/04 Containment Pressure (Subatmospheric)
B 3.6.48 BASES ACTIONS - A. 1 When containment air partial pressure is not within the limits of the LCO, containment pressure must be restored to within these limits within 1 hour. The Required Action is necessary to return operation to within the bounds of the containment analysis. The 1 hour Completion Time is consistent with the ACTIONS of LC0 3.6.1, "Containment," which requires that containment be restored to OPERABLE status within I hour. B.l and 6.2 If containment air partial pressure cannot be restored to within limits within the required Completion Time, the plant must be brought to a MODE in which the LC0 does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 5 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems. SURVEILLANCE SR 3.6.4B.l REQUIREMENTS Verifying that containment air partial pressure is within limits ensures that peration remains within the limits assumed in the containment analysis.
The 12 hour Frequency of this SR was developed considering operating P experience related to trending of containment pressure variations and pressure instrument drift during the applicable MODES. Furthermore, the 12 hour Frequency is considered adequate in view of other indications REFERENCES
: 1. FSAR, Section [6.2]. 2. 10 CFR 50, Appendix K. WOG STS Rev. 3.0, 03/31/04 BASES ACTIONS SURVEILLANCE REQUIREMENTS REFERENCES Containment Pressure (Subatmospheric)
B 3.6.4B When containment air partial pressure is not within the limits of the LCO, containment pressure must be restored to within these limits within 1 hour.The Required Action is necessary to return operation to within the bounds of the containment analysis.The 1 hour Completion Time is consistent with the ACTIONS of LCO 3.6.1,"Containment," which requires that containment be restored to OPERABLE status within 1 hour.B.1 and B.2 If containment air partial pressure cannot be restored to within limits within the required Completion Time, the plant must be brought to a MODE in which the LCO does not apply.To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 5 within 36 hours.The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.SR 3.6.4B.1 Verifying that containment air partial pressure is within limits ensures that remains within the limits assumed in the containment analysis.LIhe 12 hour Frequency of this SR was developed considering operating experience related to trending of containment pressure variations and pressure instrument drift during the applicable MODES.Furthermore, the 12 hour Frequency is considered adequate in view of other indications available in the control room, including alarms, to alert the 0 erator an abnormal containment pressure condition....1.FSAR, Section[6.2].2.10 CFR 50, Appendix K.WOGSTS B 3.6.4B-3 Rev.3.0, 03/31/04 Containment Air Temperature (Atmospheric and Dual)
B 3.6.5A BASES ACTIONS A.? When containment average air temperature is not within the limit of the LCO, it must be restored to within limit within 8 hours. This Required Action is necessary to return operation to within the bounds of the containment analysis. The 8 hour Completion Time is acceptable considering the sensitivity of the analysis to variations in this parameter and provides sufficient time to correct minor problems.
6.1 and 6.2 If the containment average air temperature cannot be restored to within its limit within the required Completion Time, the plant must be brought to a MODE in which the LC0 does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 5 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems. SURVEILLANCE SR 3.6.5A.1 REQUIREMENTS Verifying that containment average air temperature is within the LC0 limit ensures that containment operation remains within the limit assumed for the containment analyses.
In order to determine the containment average air temperature, an arithmetic average is calculated using measurements taken at locations within the containment selected to provide a representative sample of the overall containment atmosphere.
@he 24 hour Frequency of this SR is considered acceptable based on observed slow rates of temperature increase within containment as a result of environmental heat sources (due to the large volume of containment). Furthermore, the 24 hour Frequency is considered adequate in view of other indications available in the control room, including alarms, to alert the operator to an abnormal containment temperature condition.
f------ REFERENCES 1 FSAR, Section [6.2]. 2. 10 CFR 50.49. WOG STS Rev. 3.0, 03/31/04 Containment Air Temperature (Atmospheric and Dual)B 3.6.SA BASES ACTIONS When containment average air temperature is not within the limit of the LCO, it must be restored to within limit within 8 hours.This Required Action is necessary to return operation to within the bounds of the containment analysis.The 8 hour Completion Time is acceptable considering the sensitivity of the analysis to variations in this parameter and provides sufficient time to correct minor problems.8.1 and B.2 If the containment average air temperature cannot be restored to within its limit within the required Completion Time, the plant must be brought to a MODE in which the LCO does not apply.To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 5 within 36 hours.The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.SURVEILLANCE SR 3.6.5A.1 REQUIREMENTS Verifying that containment average air temperature is within the LCO limit ensures that containment operation remains within the limit assumed for the containment analyses.In order to determine the containment average air temperature, an arithmetic average is calculated using measurements taken at locations within the containment selected to Rrovide a representative sample of the overall containment atmosphere.
IThe 24 hour Frequency of this SR is considered acceptable based on observed slow rates of temperature increase within containment as a result of environmental heat sources (due to the large volume of containment).
Furthermore, the 24 hour Frequency is considered adequate in view of other indications available in the control room, including alarms, to alert the operator to an abnormal containment temperature condition..(-*---=====Cth S:<7t t i)REFERENCES 1.FSAR, Section[6.2].2.10 CFR 50.49.WOGSTS B 3.6.5A-3 Rev.3.0, 03/31/04 Containment Air Temperature (Ice Condenser)
B 3.6.5B BASES SURVEILLANCE REQUIREMENTS (continued) using measurements taken at locations within the containment selected to rovide a representative sample of the overall containment atmosphere.
The 24 hour Frequency of these SRs is considered acceptable based on e observed slow rates of temperature increase within containment as a result of environmental heat sources (due to the large volume of containment). Furthermore, the 24 hour Frequency is considered adequate in view of other indications available in the control room, including alarms, to alert the operator to an abnormal containment REFERENCES
: 1. FSAR, Section [6.2]. 2. 10 CFR 50.49. WOG STS Rev. 3.0, 03/31/04 Containment Air Temperature (Ice Condenser)
B 3.6.5B BASES SURVEILLANCE REQUIREMENTS (continued)
REFERENCES using measurements taken at locations within the containment selected to.,grovide a representative sample of the overall containment atmosphere.
llhe 24 hour Frequency of these SRs is considered acceptable based on observed slow rates of temperature increase within containment as a result of environmental heat sources (due to the large volume of containment).
Furthermore, the 24 hour Frequency is considered adequate in view of other indications available in the control room, including alarms, to alert the operator to an abnormal containment temperature condition.
_1.FSAR, Section[6.2].2.10 CFR 50.49.WOGSTS B 3.6.5B-4 Rev.3.0, 03/31/04 Containment Air Temperature (Subatmospheric)
B 3.6.5C BASES APPLICABILITY In MODES 1, 2, 3, and 4, a DBA could cause a release of radioactive material to containment.
In MODES 5 and 6, the probability and consequences of these events are reduced due to the pressure and temperature limitations of these MODES. Therefore, maintaining containment average air temperature within the limit is not required in MODE 5 or 6. ACTIONS A.1 When containment average air temperature is not within the limits of the LCO, it must be restored to within limits within 8 hours. This Required Action is necessary to return operation to within the bounds of the containment analysis. The 8 hour Completion Time is acceptable considering the sensitivity of the analysis to variations in this parameter and provides sufficient time to correct minor problems.
B.l and B.2 If the containment average air temperature cannot be restored to within its limits within the required Completion Time, the plant must be brought to a MODE in which the LC0 does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 5 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems. SURVEILLANCE SR 3.6.5C.1 REQUIREMENTS Verifying that containment average air temperature is within the LC0 limits ensures that containment operation remains within the limits assumed for the containment analyses.
In order to determine the containment average air temperature, a weighted average is calculated using measurements taken at locations within containment selected to ovide a representative sample of the overall containment atmosphere.
The 24 hour Frequency of this SR is considered acceptable based on f observed slow rates of temperature increase within containment as a result of environmental heat sources (due to the large volume of containment). Furthermore, the 24 hour Frequency is considered adequate in view of other indications available in the control room, including alarms, to alert the operator to an abnormal containment temperature condition.- . -e;z?; 2 WOG STS B 3.6.56-3 Rev. 3.0, 03/31/04 BASES APPLICABILITY ACTIONS SURVEILLANCE REQUIREMENTS Containment Air Temperature (Subatmospheric)
B 3.6.5C In MODES 1, 2, 3, and 4, a DBA could cause a release of radioactive material to containment.
In MODES 5 and 6, the probability and consequences of these events are reduced due to the pressure and temperature limitations of these MODES.Therefore, maintaining containment average air temperature within the limit is not required in MODE 5 or6.When containment average air temperature is not within the limits of the LCO, it must be restored to within limits within 8 hours.This Required Action is necessary to return operation to within the bounds of the containment analysis.The 8 hour Completion Time is acceptable considering the sensitivity of the analysis to variations in this parameter and provides sufficient time to correct minor problems.B.1 and B.2 If the containment average air temperature cannot be restored to within its limits within the required Completion Time, the plant must be brought to a MODE in which the LCO does not apply.To achieve this status.the plant must be brought to at least MODE 3 within 6 hours and to MODE 5 within 36 hours.The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.SR 3.6.5C.1 Verifying that containment average air temperature is within the LCO limits ensures that containment operation remains within the limits assumed for the containment analyses.In order to determine the containment average air temperature, a weighted average is calculated using measurements taken at locations within containment selected to..,gr0vide a representative sample of the overall containment atmosphere.
Uhe 24 hour Frequency of this SR is considered acceptable based on observed slow rates of temperature increase within containment as a result of environmental heat sources (due to the large volume of containment).
Furthermore, the 24 hour Frequency is considered adequate in view of other indications available in the control room, including alarms, to alert the operator to an abnormal containment temperature
:Cn5e r" WOGSTS B 3.6.5C-3 Rev.3.0, 03/31/04 Containment Spray and Cooling Systems (Atmospheric and Dual)
B 3.6.6A BASES ACTIONS (continued)
*.I and E.2 If the Required Action and associated Completion Time of Condition C or D of this LC0 are not met, the plant must be brought to a MODE in which the LC0 does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 5 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems. Wtth two containment spray trains or any combination of three or more containment spray and cooling trains inoperable, the unit is in a condition , outside the accident analysis. Therefore, LC0 3.0.3 must be entered immediately.
\ SURVEILLANCE Sf? 3.8.6A.1 REQUIREMENTS Verifying the correct alignment for manual, power operated, and automatic valves in the containment spray flow path provides assurance that the proper flow paths will exist for Containment Spray System f reauencv is operation. This SR does not apply to valves that are locked, sealed, or based on engineering judgment, is consistent with the procedural controls governing valve operation, and ensures \ correct valve \ otherwise secured in position, si'nce these were verified to be in the correct position prior to locking, sealing, or securing. This SR does not require any testing or valve manipulation. Rather, it involves verification that those valves outside containment (only check valves are inside containment) and capable of potentially being mispositioned are in the correct position.
+ Operating each [required] containment cooling train fan unit for 2 15 minutes ensures that all trains are OPERABLE and that all associated controls are functioning properly.
It also ensures that blockage, fan or m tor failure, or excessive vibration can be detected for corrective action. I? he 31 day Frequency was developed considering the known reliability of the fan units and controls, the two train redundancy available, and the low probability of significant degradation of the containment cooling train occurring between surveillances.
It has also been shown to be acceptable through operating ex WOG STS B 3.6.6A-7 Rev. 3.1, 12/01/05 Containment Spray and Cooling Systems (Atmospheric and Dual)B 3.6.6A BASES ACTIONS (continued)
E.1 and E.2 If the Required Action and associated Completion Time of Condition C or D of this LCO are not met, the plant must be brought to a MODE in which the LCO does not apply.To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and toMODE 5 within36hours.The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.E.J.SR 3.6.6A.1 VVith two containment spray trains or any combination of three or more containment spray and cooling trains inoperable, the unit is in a condition outside the accident analysis.Therefore, LCO 3.0.3 must be entered immediately.
Verifying the correct alignment for manual, power operated, and automatic valves in the containmentsprayflow path provides assurance that the proper flow paths will exist for Containment Spray System operation.
This SR does not apply to valves that are locked, sealed, or otherwise secured in position, since these were verified to be in the correct position prior to locking, sealing, or securing.This SR does not require any testing or valve manipulation.
Rather, it involves verification that those valves outside containment (only check valves are inside containment) and capable of potentially being mispositioned are in the correct position.SR 3.6.6A.2 Operating each[required}
containment cooling train fan unit for15 minutes ensures that all trains are OPERABLE and that all associated controls are functioning properly.It also ensures that blockage, fan or I1)Qtor failure, or excessive vibration can be detected for corrective action.LIhe 31 day Frequency was developed considering the known reliability of the fan units and controls, the two train redundancy available, and the low probability of significant degradation of the containment cooling train occurring between surveillances.
It has also been shown to be acceptable through operatingC!-
:l SURVEILLANCE REQUIREMENTS
[The 31 day Frequency is based on engineering judgment, is consistent with the procedural controls governing valve operation, and ensures correct valve
.....
WOGSTS B 3.6.6A-7 Rev.3.1, 12/01/05 Containment Spray and Cooling Systems (Atmospheric and Dual)
B 3.6.6A BASES SURVEILLANCE REQUIREMENTS (continued)
Verifying that each [required]
containment cooling train ESW cooling flow rate to each cooling unit is 2 [700] gpm provides assurance that the design flow rate assumed in the safety analyses will be achieved (Ref. 3). &fhe Frequent-bwas developed considering the known reliability of the Cooling Water System, the two train redundancy available, and the low probabilitv of a significant degradation of flow occurring between Verifying each containment spray pump's developed head at the flow test point is greater than or equal to the required developed head ensures that spray pump performance has not degraded during the cycle. Flow and differential pressure are normal tests of centrifugal pump performance required by the ASME Code (Ref. 8). Since the containment spray pumps cannot be tested with flow through the spray headers, they are tested on recirculation flow. This test confirms one point on the pump design curve and is indicative of overall performance. Such inservice tests confirm component OPERABILITY, trend performance, and detect incipient failures by abnormal performance. The Frequency of the SR is in accordance with the lnservice Testing Program.
SR 3.6.6~.5 and SR 3.6.6A.6 These SRs require verification that each automatic containment spray valve actuates to its correct position and that each containment spray pump starts upon receipt of an actual or simulated actuation of a containment High3 pressure signal. This Surveillance is not required for valves that are locked, sealed, or otherwise secured in the required position under administrative controls.
Ehe [18] month Frequency is based on the need to perform these Surveillances under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillances were performed with the reactor at power. Operating experience has shown that these components usually pass the Surveillances when performed at the [I81 month Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.
The surveillance of containment sump isolation valves is also required by SR 3.5.2.5. A single surveillance may be used to satisfy both requirements.
WOG STS B 3.6.6A-8 Rev. 3.1, 12/01/05 Containment Spray and Cooling Systems (Atmospheric and Dual)B 3.6.6A BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.6.6A.3 Verifying that each[requiredJ containment cooling train ESW cooling flow rate to each cooling unit is 2:[700J gpm provides assurance that the-T'--design flow rate assumed in the safety analyses will be achieved (Ref.3).......WL....*__.:..-..:3'-'-f
........C\"""....I;CLa:;...;..:::y&#xa5;'5::::;..;
........
developed considering the known reliability of the Cooling Water System, the two train redundancy available, and the low probability of a significant degradation of flow occurring between surveillances.SR 3.6.6A.4 Verifying each containment spray pump's developed head at the flow test point is greater than or equal to the required developed head ensures that spray pump performance has not degraded during the cycle.Flow and differential pressure are normal tests of centrifugal pump performance required by the ASME Code (Ref.8).Since the containment spray pumps cannot be tested with flow through the spray headers, they are tested on recirculation flow.This test confirms one point on the pump design curve and is indicative of overall performance.
Such inservice tests confirm component OPERABILITY, trend performance, and detect incipient failures by abnormal performance.
The Frequency of the SR is in accordance with the Inservice Testing Program.SR3.6.6A.5 and SR 3.6.6A.6 These SRs require verification that each automatic containment spray valve actuates to its correct position and that each containment spray pump starts upon receipt of an actual or simulated actuation of a containment High-3 pressure signal.This Surveillance is not required for valves that are locked, sealed, or otherwise secured in the required position under administrative controls.!lhe
[18J month Frequency is based on the need to perform these Surveillances under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillances were performed with the reactor at power.Operating experience has shown that these components usually pass the Surveillances when performed at the[18]month Frequency.
Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.
"*"" G.&sect; The surveillance of containment sump isolation valves is also reqUired by SR 3.5.2.5.A single surveillance may be used to satisfy both requirements.
WOG STS B 3.6.6A-8 Rev.3.1, 12101/05 Containment Spray and Cooling Systems (Atmospheric and Dual)
I3 3.6.6A BASES SURVEILLANCE REQUIREMENTS (continued)
This SR requires verification that each [required] containment cooling train actuates upon receipt of an actual or simulated safety injection signal.che
[I81 month Frequency is based on engineering judgment and has been shown to be acceptable through operating experience.
See SR 3.6.6A.5 and SR 3.6.6A.6, above, for further discussion of the basis for the [I81 month Frequency.
6-. e7r'.T;-r_;f i.') With the containment spray inlet valves closed and the spray header drained of any solution, low pressure air or smoke can be blown through test connections. This SR ensures that each spray nozzle is unobstructed and provides assurance that spray verage of the containment during an accident is not degraded.
(? Due to the passive design of the nozzle, a test at [the first refueling and at] 10 is considered adequate to detect obstruction of the nozzles. REFERENCES
: 1. 10 CFR 50, Appendix A, GDC 38, GDC 39, GDC 40, GDC 41, GDC 42, and GDC 43. 2. 10 CFR 50, Appendix K. 3. FSAR, Section [ 1. 4. FSAR, Section [ 1. 5. FSAR, Section
[ 1. 6. FSAR, Section [ 1. 7. FSAR, Section [ 1. 8. ASME Code for Operation and Maintenance of Nuclear Power Plants. WOG STS Rev. 3.1, 12/01/05 Containment Spray and Cooling Systems (Atmospheric and Oual)B 3.6.6A BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.6.6A.7 This SR requires verification that each[required]
containment cooling train actuates upon receipt of an actual or simulated safety injection signal.l!he
[18]month Frequency is based on engineering judgment and has been shown to be acceptable through operating experience.
See SR 3.6.6A.5 and SR 3.6.6A.6, above, for further discussion of the basis for the[18]month Frequency.
..\
SR 3.6.6A.8 With the containment spray inlet valves closed and the spray header drained of any solution, low pressure air or smoke can be blown through test connections.
This SR ensures that each spray nozzle is unobstructed and provides assurance that spraY..90verage of the containment during an accident is not degraded.LPue to the passive design of the nozzle, a test at[the first refueling and at]10 year interva=!!.lj;I.-_--:-_....
is considered adequate to detect obstruction of the nozzles.n::eX t,.REFERENCES 1.10 CFR 50, Appendix A, GDC 38, GOG 39, GOC 40, GOC 41, GOG 42, and GOC 43.2.10 CFR 50, Appendix K.3.FSAR, Section[J.4.FSAR, Section[].5.FSAR, Section[].6.FSAR, Section[].7.FSAR, Section[J.8.ASME Code for Operation and Maintenance of Nuclear Power Plants.WOGSTS B 3.6.6A-9 Rev.3.1,12/01/05 Containment Spray and Cooling Systems (Atmospheric and Dual) B 3.6.6B BASES SURVEILLANCE SR 3.6.68.1 REQUIREMENTS Verifying the correct alignment for manual, power operated, and ec The 31 day C Frequency is based on engineering judgment, is consistent with the procedural automatic valves, excluding check valves, in the Containment Spray System flow path provides assurance that the proper flow path exists for Containment Spray System operation.
This SR does not apply to valves that are locked, sealed, or otherwise secured in position, since these were verified to be in the correct positions prior to being secured.
This SR does not require testing or valve manipulation. Rather, it involves verification that those valves outside containment (only check valves are inside containment) and capable of potentially being mispositioned are in the correct position.
I_Cr controls SR 3.6.6B.2 governing valve operation, and \ ensures I correct valve I Operating each [required] containment cooling train fan unit for r 15 minutes ensures that all trains are OPERABLE and all associated controls are functioning properly.
It also ensures that blockage, fan or motor failure, or excessive vibration can be detected for corrective action.
Cfhe 31 day Frequency was developed based on the known reliability of the fan units and controls, the two train redundancy available, and the low probability of significant degradation of the containment cooling train occurring between SR 3.6.6B.3 Verifying that each [required] containment cooling train ESW cooling flow rate to each cooling unit is 2 [700] gpm provides assurance that the design flow rate assumed in the analyses will be achieved (Ref.
3). Ehe Frequenchwas developed considering the known reliability of the Cooling Water System, the two train redundancy available, and the low probability of a significant degradation of flow occurring between surveillances&?
SR 3.6.6B.4 --' Verifying that each containment spray pump's developed head at the flow test point is greater than or equal to the required developed head ensures that spray pump performance has not degraded during the cycle. Flow and differential pressure are normal tests of centrifugal pump performance required by the ASME Code (Ref.
8). Since the containment spray pumps cannot be tested with flow through the spray headers, they are tested on recirculation flow. This test confirms one point on the pump design curve and is indicative of overall performance.
Such inservice WOG STS B 3.6.6B-7 Rev. 3.1, 12/01/05 SURVEILLANCE REQUIREMENTS Containment Spray and Cooling Systems (Atmospheric and Dual)B 3.6.68 Verifying the correct alignment for manual, power operated, and automatic valves, excluding check valves, in the Containment Spray System flow path provides assurance that the proper flow path exists for Containment Spray System operation.
This SR does not apply to valves that are locked, sealed, or othelWise secured in position, since these were verified to be in the correct positions prior to being secured.This SR does not require testing or valve manipulation.
Rather, it involves verification that those valves outside containment (only check valves are inside containment) and capable of potentially being mispositioned are in the correct position.SR 3.6.6B.2 SR 3.6.68.1 Operating each[required]
containment cooling train fan unit for;;:: 15 minutes ensures that all trains are OPERABLE and all associated controls are functioning properly.It also ensures that blockage, fan or motor failure, or excessive vibration can be detected for corrective action.[The 31 day Frequency was developed based on the known reliability of the fan units and controls, the two train redundancy available, and the low probability of significant degradation of the containment cooling train occurring between
(..L Vl:e'"FSR 3.6.6B.3._-[he 31 day Frequency is based on engineering judgment, is consistent with the procedural controls governing valve operation, and ensures correct valve(I>1ser t])Verifying that each[required]
containment cooling train ESW cooling flow rate to each cooling unit is[700]gpm provides assurance that the design flow rate assumed in the analyses will be achieved (Ref.3).[]he developed considering the known reliability of the Cooling Water System, the two train redundancy available, and the low probability of a significant degradation of flow occurring between
..
SR 3.6.68.4----'Verifying that each containment spray pump's developed head at the flow test point is greater than or equal to the required developed head ensures that spray pump performance has not degraded during the cycle.Flow and differential pressure are normal tests ofcentrifugalpump performance required by the ASME Code (Ref.8).Since the containment spray pumps cannot be tested with flow through the spray headers, they are tested on recirculation flow.This test confirms one point on the pump design curve and is indicative of overall performance.
Such inservice WOGSTS B 3.6.68-7 Rev.3.1, 12/01/05 Containment Spray and Cooling Systems (Atmospheric and Dual) B 3.6.6B BASES SURVEILLANCE REQUIREMENTS (continued) inspections confirm component OPERABILITY, trend pedormance, and detect incipient failures by indicating abnormal performance. The Frequency of this SR is in accordance with the lnservice Testing Program. SR 3.6.68.5 and SR 3.6.6B.6 These SRs require verification that each automatic containment spray valve actuates to its correct position and that each containment spray pump starts upon receipt of an actual or simulated containment High-3 pressure signal. This Surveillance is not required for valves that are locked, sealed, or otherwise secured in the required position under administrative controls.Ehe
[18] month Frequency is based on the need to perform these Surveillances under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillances were performed with the reactor at power. Operating experience has shown that these components usually pass the Surveillances when performed at the
[I81 month Frequency. Therefore, the Frequency was concluded to - be acceptable from a reliability standpoint.
4- ---<z rfiert 0 The surveillance of containment sump isolation valves is atso required by SR 3.5.2.5. A single surveillance may be used to satisfy both requirements.
This SR ensures that each [required] containment cooling train actuates upon receipt of an actual or simulated safety injection signal. che [I81 month Frequency is based on engineering judgment and has been proven acceptable through operating experience. See SR 3.6.6B.5 and SR 3.6.6B.6, above, for further discussion of the basis for the [I81 month Frequency.
C--...%<~XT~~) - WOG STS B 3.6.68-8 Rev. 3.1, 12/01/05 Containment Spray and Cooling Systems (Atmospheric and Dual)B 3.6.6B BASES SURVEILLANCE REQUIREMENTS (continued) inspections confirm component OPERABILITY, trend performance, and detect incipient failures by indicating abnormal performance.
The Frequency of this SR is in accordance with the Inservice Testing Program.SR 3.6.6B.5 and SR 3.6.6B.6 These SRs require verification that each automatic containment spray valve actuates to its correct position and that each containment spray pump starts upon receipt of an actual or simulated containment High-3 pressure signal.This Surveillance is not required for valves that are locked, sealed, or otherwise secured in the required position under administrative controls.L!he
[18]month Frequency is based on the need to perform these Surveillances under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillances were performed with the reactor at power.Operating experience has shown that these components usually pass the Surveillances when performed at the[18]month Frequency.
Therefore, the Frequency was conclu..Qed to be from a reliability standpoint.
.(-..-----(2: r6ert V The surveillance of containment sump isolation valves is also required by SR 3.5.2.5.A single surveillance may be used to satisfy both requirements.
SR 3.6.6B.7 This SR ensures that each[required]
containment cooling train actuates upon receipt of an actual or simulated safety injection signal.IThe[18]month Frequency is based on engineering judgment and has been proven acceptable through operating experience.
See SR 3.6.6B.5 and SR 3.6.6B.6, above, for further discussion of the basis for the[18)month Frequency..(---""-6" nS WOGSTS B 3.6.6B-8 Rev.3.1,12/01/05 Containment Spray and Cooling Systems (Atmospheric and Dual) B 3.6.68 BASES SURVEILLANCE REQUIREMENTS (continued)
With the containment spray inlet valves closed and the spray header drained of any solution, low pressure air or smoke can be blown through test connections.
This SR ensures that each spray nozzle is unobstructed and that spra coverage of the containment during an accident is not degraded.&cause of the passive design of the nozzle, a test at [the first refueling and at] 10 year intervals is considered adequate - to detect obstruction of the spray nozzles.
C\(rnc - 2 ) REFERENCES
: 1. 10 CFR 50, Appendix A, GDC 38, GDC 39, GDC 40, GDC 41, GDC 42, and GDC 43. 2. 10 CFR 50, Appendix A. 3. FSAR, Section [15]. 4. FSAR, Section [6.2]. 5. FSAR, Section [ 1. 6. FSAR, Section [ 1. 7. FSAR, Section [ 1. 8. ASME Code for Operation and Maintenance of Nuclear Power Plants. WOG STS Rev. 3.1, 12/01/05 Containment Spray and Cooling Systems (Atmospheric and Oual)B 3.6.68 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.6.6B.8 With the containment spray inlet valves closed and the spray header drained of any solution, low pressure air or smoke can be blown through test connections.
This SR ensures that each spray nozzle is unobstructed and thatcoverage of the containment during an accident is not of the passive design of the nozzle, a test at[the first refueling and at}1&deg;year intervals is considered adequate to detect obstruction of the spray nozzles.-E::'"-.....
c"T REFERENCES 1.10 CFR 50, Appendix A, GOC 38, GOC 39, GOC 40, GDC 41, GOC 42, and GDC 43.2.10 CFR 50, Appendix A.3.FSAR, Section[15].4.FSAR, Section[6.2J.5.FSAR, Section[}.6.FSAR, Section[J.7.FSAR, Section[J.8.ASME Code for Operation and Maintenance of Nuclear Power Plants.WOGSTS B 3.6.6B-9 Rev.3.1,12/01/05 Containment Spray System (Ice Condenser)
B 3.6.6C BASES APPLICABILITY In MODES 1, 2, 3, and 4, a DBA could cause a release of radioactive material to containment and an increase in containment pressure and temperature requiring the operation of the Containment Spray System.
In MODES 5 and 6, the probability and consequences of these events are reduced because of the pressure and temperature limitations of these MODES. Thus, the Containment Spray System is not required to be OPERABLE in MODE 5 or 6. ACTIONS A.1 With one containment spray train inoperable, the affected train must be restored to OPERABLE status within 72 hours. The components in this degraded condition are capable of providing 100% of the heat removal and iodine removal needs after an accident.
The 72 hour Completion Time was developed taking into account the redundant heat removal and iodine removal capabilities afforded by the OPERABLE train and the low probability of a DBA occurring during this period. B.1 and B.2 If the affected containment spray train cannot be restored to OPERABLE status within the required Completion Time, the plant must be brought to a MODE in which the LC0 does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 5 within 84 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems. The extended interval to reach MODE 5 allows additional time and is reasonable when considering that the driving force for a release of radioactive material from the Reactor Coolant System is reduced in MODE 3. SURVEILLANCE SR 3.6.6C. 1 REQUIREMENTS Verifying the correct alignment of manual, power operated, and automatic valves, excluding check valves, in the Containment Spray System provides assurance that the proper flow path exists for Containment Spray System operation.
This SR does not apply to valves that are locked, sealed, or otherwise secured in position since they were verified
: e. 7. in the correct position prior to being secured. This SR does not require any testing or valve manipulation. Rather, it involves verification that those valves outside containment and capable of potentially being mispositioned, are in the correct position.
?__ --<*. n~~"-~-"----"--"~yr 6he 31 day Frequency is based on engineering judgment, is consistent with the procedural controls governing valve operation, and ensures correct valve positions.
-*__l-m_ --..---*Y--u---
ll~-".*Y**41m"ll.YU
--- *I c WOG STS B 3.6.6C-5 Rev. 3.1, 12/01/05 Containment Spray System (Ice Condenser)
B3.6.6C BASES APPLICABI L1TY In MODES 1, 2, 3, and 4, a DBA could cause a release of radioactive material to containment and an increase in containment pressure and temperature requiring the operation of the Containment Spray System.In MODES 5 and 6, the probability and consequences of these events are reduced because of the pressure and temperature limitations of these MODES.Thus, the Containment Spray System is not required to be OPERABLE in MODE 5 or 6.ACTIONS With one containment spray train inoperable, the affected train must be restored to OPERABLE status within 72 hours.The components in this degraded condition are capable of providing 100%of the heat removal and iodine removal needs after an accident.The 72 hour Completion Time was developed taking into account the redundant heat removal and iodine removal capabilities afforded by the OPERABLE train and the low probability of a DBA occurring during this period.B.1 and B.2 If the affected containment spray train cannot be restored to OPERABLE status within the required Completion Time, the plant must be brought to a MODE in which the LCO does not apply.To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 5 within 84 hours.The allowed Completion Times are reasonable, based onoperatingexperience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.The extended interval to reach MODE 5 allows additional time and is reasonable when considering that the driving force for a release of radioactive material from the Reactor Coolant System is reduced in MODE 3.SURVEILLANCE SR 3.6.6C.1 REQUIREMENTS Verifying the correct alignment of manual, power operated, and automatic valves, excluding check valves, in the Containment Spray System Z{3a.,..ses, h/(rM provides assurance that the proper flow path exists for Containment
,'it'/"" Sf?SpraySystemoperation.This SR does not apply to valves that are*froN'<S,II'YII<*/locked, sealed, or otherwise secured in position since they were verified e.7'SR 7,'7,:;, I)in the, position pri?r to
..This SR n?t require , any testing or valve mampulatlon.
Rather, It Involves verification that those valves outside containment and capable of potentially being..
___'__Uhe 31 day Frequency is based on engineering judgment, is consistent with the procedural WOGSTS B 3.6.6C-5 Rev.3.1, 12/01/05 Containment Spray System (Ice Condenser)
B 3.6.6C BASES SURVEILLANCE REQUIREMENTS (continued)
Verifying that each containment spray pump's developed head at the flow test point is greater than or equal to the required developed head ensures that spray pump performance has not degraded during the cycle. Flow and differential head are normal tests of centrifugal pump performance required by the ASME Code (Ref.
5). Since the containment spray pumps cannot be tested with flow through the spray headers, they are tested on bypass flow. This test confirms one point on the pump design curve and is indicative of overall performance. Such inservice inspections confirm component OPERABILITY, trend performance, and detect incipient failures by indicating abnormal performance.
The Frequency of this SR is in accordance with the lnservice Testing Program.
SR 3.6.6.3 and SR 3.6.6.4 These SRs require verification that each automatic containment spray valve actuates to its correct position and each containment spray pump starts upon receipt of an actual or simulated containment spray actuation signal. This Surveillance is not required for valves that are locked, sealed, o otherwise secured in the required position under administrative controkbhe 1181 month Frequency is based on the need to perform these Surveillances under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillances were performed with the reactor at power. Operating experience has shown these components usually pass the Surveillances when performed at the [I81 month Frequency. Therefore, the Frequency was concluded to be acceptable from a reiability standpoint.
(%- _ -, The surveillance of containment sump isolation valves IS also required by SR 3.6.6.3. A single surveillance may be used to satisfy both requirements. With the containment spray inlet valves closed and the spray header drained of any solution, low pressure air or smoke can be blown through test connections. This SR ensures that each spray nozzle is unobstructed and that spra coverage of the containment during an accident is not degraded.
2 Because of the passive design of the nozzle, a test at [the first refueling and at] 10 year intervals is considered adequate to detect obstruction of the spray nozzles.
h-(?,Sem)
WOG STS B 3.6.6C-6 Rev. 3.1, 12/01/05 Containment Spray System (Ice Condenser)
B 3.6.6C BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.6.6.2 Verifying that each containment spray pump's developed head at the flow test point is greater than or equal to the required developed head ensures that spray pump performance has not degraded during the cycle.Flow and differential head are normal tests of centrifugal pump performance required by the ASME Code (Ref.5).Since the containment spray pumps cannot be tested with flow through the spray headers, they are tested on bypass flow.This test confirms one point on the pump design curve and is indicative of overall performance.Suchinservice inspections confirm component OPERABILITY, trend performance, and detect incipient failures by indicating abnormal performance.
The Frequency of this SR is in accordance with the Inservice Testing Program.SR 3.6.6.3 and SR 3.6.6.4 These SRs require verification that each automatic containment spray valve actuates to its correct position and each containment spray pump starts upon receipt of an actual or simulated containment spray actuation signal.This Surveillance is not required for valves that are locked, sealed, o;:".3therwise secured in the required position under administrative controls.LIhe
[18}month Frequency is based on the need to perform these Surveillances under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillances were performed with the reactor at power.Operating experience has shown these components usually pass the Surveillances when performed at the[18]month Frequency.
Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.-,-", Q:-!\5eThe surveillance of containment sump isolation valves is also required by SR 3.6.6.3.A single surveillance may be used to satisfy both requirements.
SR 3.6.6.5 With the containment spray inlet valves closed and the spray header drained of any solution, low pressure air or smoke can be blown through test connections.
This SR ensures that each spray nozzle is unobstructed and thatcoverage of the containment during an accident is not degradedl&sect;ecause of the passive design of the nozzle, a test at[the first refueling and atJ 10 year intervals is considered adequate to detect obstruction of the spray nozzles._In3er*t 2-WOGSTS B 3.6.6C-6 Rev.3.1, 12/01/05 QS System (Subatmospheric)
B 3.6.6D BASES ACTIONS A.1 If one QS train is inoperable, it must be restored to OPERABLE status within 72 hours. The components in this degraded condition are capable of providing 100% of the heat removal and iodine removal needs after an accident.
The 72 hour Completion Time was developed taking into account the redundant heat removal and iodine removal capabilities afforded by the OPERABLE train and the low probability of a DBA occurring during this period. B.1 and B.2 If the Required Action and associated Completion Time are not met, the plant must be brought to a MODE in which the LC0 does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 5 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required Y~J~,s, i> plant conditions from full power conditions in an orderly manner and without challenging plant systems.
/ SURVEILLANCE SR 3.6.6D.1 REQUIREMENTS 1 Frequency is based on engineering judgment, is consistent with the procedural controls governing valve operation, and ensures correct valve positions Verifying the correct alignment of manual, power operated, and automatic valves, excluding check valves, in the QS System provides assurance that the proper flow path exists for QS System operation.
This SR does not apply to valves that are locked, sealed, or otherwise secured in position, since they were verified to be in the correct position prior to being secured.
This SR does not require any testing or valve manipulation. Rather, it involves verification that those valves outside containment and capable of potentially being mispositioned are in the correct position.
4 Verifying that each QS pump's developed head at the flow test point is greatcar than or equal to the required developed head ensures that QS pump performance has not degraded during the cycle. Flow and differential head are normal tests of centrifugal pump performance required by the ASME Code (Ref.
4). Since the QS System pumps cannot be tested with flow through the spray headers, they are tested on I bypass flow. This test confirms one point on the pump design curve and is indicative of overall performance. Such inservice tests confirm component OPERABILITY, trend performance, and detect incipient failures by indicating abnormal performance.
The Frequency of this SR is in accordance with the Inservice Testing Program. WOG STS -- Rev. 3.1, 12/01/05 BASES ACTIONS SURVEILLANCE REQUIREMENTS
[The 31 day Frequency is based on engineering judgment, is consistent with the procedural controls governing valve operation, and ensures correct valve(fV1!:::V QS System (Subatmospheric)
B 3.6.60 If one OS train is inoperable, it must be restored to OPERABLE status within 72 hours.The components in this degraded condition are capable of providing 100%of the heat removal and iodine removal needs after an accident.The 72 hour Completion Time was developed taking into account the redundant heat removal and iodine removal capabilities afforded by the OPERABLE train and the low probability of a DBA occurring during this period.B.1 and B.2 If the Required Action and associated Completion Time are not met, the plant must be brought to a MODE in which the LCO does not apply.To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 5 within 36 hours.The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.SR 3.6.60.1 Verifying the correct alignment of manual, power operated, and automatic valves, excluding check valves, in the OS System provides assurance that the proper flow path exists for QS System operation.
This SR does not apply to valves that are locked, sealed, or otherwise secured in position, since they were verified to be in the correct position prior to being secured.This SR does not require any testing or valve manipulation.
Rather, itinvolvesverification that those valves outside containment and capable of potentially being mispositioned are in the correct position.SR 3.6.60.2 Verifying that each OS pump's developed head at the flow test point is than or equal to the required developed head ensures that OS pump performance has not degraded during the cycle.Flow and differential head are normal tests of centrifugal pump performance required by the ASME Code (Ref.4).Since the OS System pumps cannot be tested with flow through the spray headers, they are tested on bypas.s flow.This test confirms one point on the pump design curve and is indicative of overall performance.
Such inservice tests confirm comp1onent OPERABILITY, trend performance, and detect incipient failures by indicating abnormal performance.
The Frequency of this SR is in accordance with the Inservice Testing Program.WOGSTS B 3.6.60-4 Rev.3.1, 12/01/05 QS System (Subatmospheric)
B 3.6.6D BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.6.6D.3 and SR 3.6.6D.4 These SRs ensure that each QS automatic valve actuates to its correct position and each QS pump starts upon receipt of an actual or simulated containment spray actuation signal. This Surveillance is not required for valves that are locked, sealed, or othenv'se secured in the required position under administrative controls.
$he [I 81 month Frequency is based on the need to perform these Surveillances under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillances were performed with the reactor at power. Operating experience has shown that these components usually pass the Surveillances when performed at an [I81 month Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.
fx- __-.+...+
r..-ll-.,.
eSed ,-+./+ 27 With the containment spray inlet valves closed and the spray header drained of any solution, low pressure air or smoke can be blown through test connections. This SR ensures that each spray nozzle is unobstructed and that spra coverage of the containment during an accident is not degraded.
iue to the passive nature of the design of the nozzle, a test at [the first refueling and at1 10 year intervals is considered - - adequate to det;ct obstruction ofthe nozzles. f-\_ REFERENCES 1 FSAR, Section [6.2]. 2. 10 CFR 50.49. 3. 10 CFR 50, Appendix K. 4. ASME Code for Operation and Maintenance of Nuclear Power Plants. WOG STS Rev. 3.1, 12!01105 QS System (Subatmospheric)
B 3.6.60 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.6.60.3 and SR 3.6.60.4 These SRs ensure that each as automatic valve actuates to its correct position and each QS pump starts upon receipt of an actual or simulated containment spray actuation signal.This Surveillance is not required for valves that are locked, sealed, or secured in the required position under administrative controls.\.lhe[18]month Frequency is based on the need to perform these Surveillances under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillances were performed with the reactor at power.Operating experience has shown that these components usually pass the Surveillances when performed at an[18]month Frequency.
Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.
SR 3.6.
 
==60.5 REFERENCES==
 
With the containment spray inlet valves closed and the spray header drained of any solution, low pressure air or smoke can be blown through test connections.
This SRensuresthat each spray nozzle is unobstructed and thatcoverage of the containment during an accident is not degraded.(Que to the passive nature of the design of the nozzle, a test at[the first refueling and at]10 year intervals is considered adequate to detect obstruction of the nozzles.1.FSAR, Section[6.2].2.10 CFR 50.49.3.10 CFR 50, Appendix K.4.ASME Code for Operation and Maintenance of Nuclear Power Plants.WOGSTS B 3.6.60-5 Rev.3.1, 12/01/05 RS System (Subatmospheric)
B 3.6.6E BASES ACTIONS (continued) With three or more RS subsystems inoperable, the unit is in a condition outside the accident analysis. Therefore, LC0 3.0.3 must be entered immediately. SURVEILLANCE SR 3.6.6E.1 REQUIREMENTS Verifying that the casing cooling tank solution temperature is within the specified tolerances provides assurance that the water injected into the suction of the outside RS pumps will increase the NPSH available as per design.Ehe 24 hour Frequency of this SR was developed considering operating experience related to the parameter variations and instrument drift during the applicable MODES. Furthermore, the 24 hour Frequency is considered adequate in view of other indications available in the control room, including alarms, to alert the operator to an abnormal condition.
4- SR 3.6.6E.2 Verifying the casing cooling tank contained borated water volume provides assurance that sufficient water is available to support the outside RS subsystem pumps during the time they are required to operatechhe 7 day Frequency of this SR was developed considering operating experience related to the parameter variations and instrument drift during the applicable MODES. Furthermore, the 7 day Frequency is considered adequate in view of other indications available in the control room, including alarms, to alert the operator to an abnormal conditione-7 KseXtj Verifying the boron concentration of the solution in the casing cooling tank provides assurance that borated water added from the casing cooling tank to RS subsystems will not dilute the solution being recirculated in the containment sump.
@e 7 day Frequency of this SR was developed considering the known stability of stored borated water and the low probability of any source of diluting pure water.
6 j5S4e2~ WOG STS B 3.6.6E-6 Rev. 3.1, 12/01/05 RS System (Subatmospheric)
B 3.6.6E BASES ACTIONS (continued)
With three or more RS subsystems inoperable, the unit is in a condition outside the accident analysis.Therefore, LCO 3.0.3 must be entered immediately.
SURVEILLANCE REQUIREMENTS SR 3.6.6E.1 Verifying that the casing cooling tank solution temperature is within the specified tolerances provides assurance that the water injected into the suction of the outside RS pumps will increase the NPSH available as per design.l1.he 24 hour Frequency of this SR was developed considering operating experience related to the parameter variations and instrument drift during the applicable MODES.Furthermore, the 24 hour Frequency is considered adequate in view of other indications available in the control room, including alarms, to alert the operator to an abnorma(f;1 co.
..:r:
SR 3.6.6E.2 Verifying the casing cooling tank contained borated water volume provides assurance that sufficient water is available to support the outside RS subsystem pumps during the time they are required to operate.llhe 7 day Frequency of this SR was developed considering operating experience related to the parameter variations and instrument drift during the applicable MODES.Furthermore, the 7 day Frequency is considered adequate in view of othe'r indications available in the control room, including alarms, to alert the operator to an abnormal SR 3.6.6E.3 Verifying the boron concentration of the solution in the casing cooling tank provides assurance that borated water added from the casing cooling tank to RS SUbsystems will not dilute the solution being recirculated in the containment sump.\!5e 7 day Frequency of this SR was developed considering the known stability of stored borated water and the low probability of any source of diluting pure water.
--t-?j"Lt'15er L WOGSTS B3.6.6E-6 Rev.3.1, 12/01/05 RS System (Subatmospheric)
B 3.6.E BASES SURVEILLANCE REQUIREMENTS (continued) ( nhe 31 day 1 ( Frequency is \ I based on engineering judgment, is consistent with the I procedural controls ) governing valve 1: I operation, and \ ensures 1 \ correct valve 1 Verifying the correct alignment of manual, power operated, and automatic valves, excluding check valves, in the RS System and casing cooling tank provides assurance that the proper flow path exists for operation of the RS System.
This SR does not apply to valves that are locked, sealed, or otherwise secured in position, since they are verified as being in the correct position prior to being secured. This SR does not require any testing or valve manipulation. Rather, it involves verification that those valves outside containment and capable of potentially being mispositioned are in the correct position.
4 Verifying that each RS [and casing cooling]
pump's developed head at the flow test point is greater than or equal to the required developed head ensures that these pumps' performance has not degraded during the cycle. Flow and differential head are normal tests of centrifugal pump performance required by the ASME Code (Ref.
4). Since the QS System pumps cannot be tested with flow through the spray headers, they are tested on bypass flow. This test confirms one point on the pump design curve and is indicative of overall performance. Such inservice tests confirm component OPERABILITY, trend performance, and detect incipient failures by indicating abnormal performance. The Frequency of this SR is in accordance with the Inservice Testing Program. These SRs ensure that each automatic valve actuates and that the RS System and casing cooling pumps start upon receipt of an actual or simulated High-High containment pressure signal. Start delay times are also verified for the RS System pumps. This Surveillance is not required for valves that are locked, sealed, or otherwise secured in the required position under administrative controls.
rhe ['I81 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power. Operating experience has shown that these components usually pass the Surveillance when performed at the 1181 month Frequency.
Therefore, the Frequency was considered to be acceptable from a reliability standpoint.^_
~y16T<#-;)
WOG STS -- - Rev. 3. I, 12/01/05 RS System (Subatmospheric)
B 3.6.6E BASES Verifying that each RS[and casing cooling]pump's developed head at the flow test point is greater than or equal to the reqUired developed head ensures that these pumps'performance has not degraded during the cycle.Flow and differential head are normal tests of centrifugal pump performance required by the ASME Code (Ref.4).Since the QS System pumps cannot be tested with flow through the spray headers, they are tested on bypass flow.This test confirms one point on the pump design curve and is indicative of overall performance.
Such inservice tests confirm component OPERABILITY, trend performance, and detect incipient failures by indicating abnormal performance.
The Frequency of this SR is in accordance with the Inservice Testing Program.Verifying the correct alignment of manual, power operated, and automatic valves, excluding check valves, in the RS System and casing cooling tank provides assurance that the proper flow path exists for operation of the RS System.This SR does not apply to valves that are locked, sealed, or otherwise secured in position, since they are verified as being in the correct position prior to being secured.This SR does not reqUire any testing or valve manipulation.
Rather, it involves verification that those valves outside containment and capable of potentially being mispositioned are in the correct position.SR 3.6.6E.5 SURVEILLANCE REQUIREMENTS (continued)
SR 3.6.6EA[The 31 day Frequency is based on engineering judgment, is consistent with the procedural controls governing valve operation, and ensures correct valve/,/Ie, I;l.-".;,)0-SR3.6.6E.6 These SRs ensure that each automatic valve actuates and that the RS System and casing cooling pumps start upon receipt of an actual or simulated containment pressure signal.Start delay times are also verified for the RS System pumps.This Surveillance is not required for valves that are locked, sealed, or otherwise secured in the reqUired position under administrative controls.[The (181 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power.Operating experience has shown that these components usually pass the Surveillance when performed at the[18]month Frequency.
Therefore, the Frequency was considered to be acceptable from a reliability standpoint.ltrVlseA2/WOGSTS B 3,6.6E-7 Rev.3.1, 12/01/05 RS System (Subatmospheric)
B 3.6.6E BASES SURVEILLANCE REQUIREMENTS (continued)
This SR ensures that each spray nozzle is unobstructed and that spray coverage of the containment will meet its design bases objective.
An air or smoke test is performed through each spray header.
@ue to the passive design of the spray header and its normally dry state, a test at [the first refueling and at] 10 year intervals is considered adequate for detecting obstruction of the nozzles.
#--b ~,--.- REFERENCES I. FSAR, Section [6.2]. Gt7se.t - 2) 2. 10 CFR 50.49. 3. 10 CFR 50, Appendix K. 4. ASME Code for Operation and Maintenance of Nuclear Power Plants. WOG STS Rev. 3.1, 12/01/05 RS System (Subatmospheric)
B 3.6.6E BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.6.6E.7 REFERENCES This SR ensures that each spray nozzle is unobstructed and that spray coverage of the containment will meet its design bases objective.
An air or smoke test is performed through each spray header.illue to the passive design of the spray header and its normally dry state, a test at[the first refueling and at]10 year intervals is considered adequate for detecting obstruction of the nozzles.
-__..,.........
_.
&..J 1.FSAR, SectIon[6.2].-2.10 CFR 50.49.3.10 CFR 50, Appendix K.4.ASME Code for Operation and Maintenance of Nuclear Power Plants.WOGSTS B 3.6.6E-8 Rev.3.1,12/01/05 Spray Additive System (Atmospheric, Subatmospheric, Ice Condenser, and Dual) B 3.6.7 BASES ACTIONS (continued) we^ +ak fi.L Additive System in MODE 3 and 36 hours to reach MODE 5. This is ~:~&ia/ Sf$ e,g+ reasonable when considering the reduced pressure and temperature SR 2Z511> conditions in MODE 3 for the release of radioactive material from the Reactor Coolant System.
SURVEILLANCE SR 3.6.7.1 REQUIREMENTS Verifying the correct alignment of Spray Additive System manual, power operated, and automatic valves in the spray additive flow path provides assurance that the system is able to provide additive to the Containment Spray System in the event of a DBA. This SR does not apply to valves that are locked, sealed, or othetwise secured in position, since these based on valves were verified to be in the correct position prior to locking, sealing, engineering or securing. This SR does not require any testing or valve manipulation.
judgment, is Rather, it involves verification that those valves outside containment and consistent capable of potentially being mispositioned are in the correct position.
with the procedural SR 3.6.7.2 controls To provide effective iodine removal, the containment spray must be an governing valve alkaline solution.
Since the RWST contents are normally acidic, the operation, and volume of the spray additive tank must provide a sufficient volume of ensures \ spray additive to adjust pH for all water injected.
This SR is performed to correct valve verify the availability of sufficient NaOH solution in the Spray Additive System. rhe 184 day Frequency was developed based on the low probability of an undetected change in tank volume occurring during the SR interval (the tank is isolated during normal unit operations). Tank level is also indicated and alarmed in the control room, so that there is high confidence that a substantial change in level would SR 3.6.7.3 This SR provides verification of the NaOH concentration in the spray additive tank and is sufficient to ensure that the spra solution being injected into containment is at the correct pH level.
I? The 184 day Frequency is sufficient to ensure that the concentration level of NaOH in the spray additive tank remains within the established limits. This is based on the low likelihood of an uncontrolled change in concentration (the tank is normally isolated) and the probability that any substantial variance in tank volume will be detected.-
-- . . .- . . . - WOG STS Rev. 3.0, 03/31/04 Spray Additive System (Atmospheric, Subatmospheric, Ice Condenser, and Dual)B 3.6.7 BASES To provide effective iodine removal, the containment spray must be an alkaline solution.Since the RWST contents are normally acidic, the volume of the spray additive tank must provide a sufficient volume of spray additive to adjust pH for all water injected.This SR is performed to verify the availability of sufficient NaOH solution in the Spray Additive System.lfhe 184 day Frequency was developed based on the low probability of an undetected change in tank volume occurring during the SR interval (the tank is isolated during normal unit operations).
Tank level is also indicated and alarmed in the control room, so that there is high confidence that a substantial change in level would b.e detected]
SR 3.6.7.3 SR 3.6.7.1 Verifying the correct alignment of Spray Additive System manual, power operated, and automatic valves in the spray additive flow path provides assurance that the system is able to provide additive to the Containment Spray System in the event of a DBA.This SR does not apply to valves that are locked, sealed, or otherwise secured in position, since these valves were verified to be in the correct position prior to locking, sealing, or securing.This SR does not require any testing or valve manipulation.
Rather, it involves verification that those valves outside containment and capable of potentially being mispositioned are in the correct position...,,).SR 3.6.7.2 SURVEILLANCE REQUIREMENTS ACTIONS (continued)
E4.>lc":.,l;-f4j(,,,,,", f).-....Additive System in MODE 3 and 36 hours to reach MODE 5.This is$h,..,,;ia.-r se...e.,_reasonable when considering the reduced pressure and temperature S R7.S;I>conditions in MODE 3 for the release of radioactive material from the Reactor Coolant System.[The 31 day Frequency is based on engineering judgment, is consistent with the procedural controls governing valve operation, and ensures correct valve positions.
<C'--"'.''')........-...-.......-"'_..........,..._..
This SR provides verification of the NaOH concentration in the spray additive tank and is sufficient to ensure that the being injected into containment is at the correct pH level.LThe 184 day Frequency is sufficient to ensure that the concentration level of NaOH in the spray additive tank remains within the established limits.This is based on the low likelihood of an uncontrolled change in concentration (the tank is normally isolated)and the probability that any substantial variance.in tank volume will be detected.WOGSTS B 3.6.7-4 Rev.3.0, 03/31/04 Spray Additive System (Atmospheric, Subatmospheric, Ice Condenser, and Dual) B 3.6.7 BASES SURVEILLANCE REQUIREMENTS (continued)
This SR provides verification that each automatic valve in the Spray Additive System flow path actuates to its correct position.
This Surveillance is not required for valves that are locked, sealed, or otherwise secured in the required position under administrative controls.
Ehe [18] month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power. Operating experience has shown that these components usually pass the Surveillance when performed at the
[I81 month Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.
e, -GG-E-2] To ensure that the correct pH level is established in the borated water solution provided by the Containment Spray System, the flow rate in the Spray Additive System is verified once every 5 years. This SR provides assurance that the correct amount of NaOH will b metered into the flow path upon Containment Spray System initiation.
c" Due to the passive nature of the spray additive flow controls, the 5 year Frequency is sufficient to identify component degradation that may affect flow rate.+ REFERENCES
: 1. FSAR, Chapter [15]. WOG STS Rev. 3.0, 03/31/04 Spray Additive System (Atmospheric, Subatmospheric, Ice Condenser, and Dual)B 3.6.7 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.6.7.4 This SR provides verification that each automatic valve in the Spray Additive System flow path actuates to its correct position.This Surveillance is not required for valves that are locked, sealed, or otherwise secured in the required position under administrative controls.[1he[18]month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power.Operating experience has shown that these components usually pass the Surveillance when performed at the[18]month Frequency.
Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.
SR 3.6.
 
==7.5 REFERENCES==
 
To ensure that the correct pH level is established in the borated water solution provided by the Containment Spray System, the flow rate in the Spray Additive System is verified once every 5 years.This SR provides assurance that the correct amount of NaOH willmetered into the flow path upon Containment Spray System initiation.LDue to the passive nature of the spray additive flow controls, the 5 year Frequency is sufficient to identify component degradation that may affect flow 1.FSAR, Chapter[15].WOGSTS B 3.6.7-5 Rev.3.0, 03/31/04 Shield Building (Dual and Ice Condenser)
B 3.6.8 BASES ACTIONS In the event shield building OPERABILITY is not maintained, shield building OPERABILITY must be restored within 24 hours. Twenty-four hours is a reasonable Completion Time considering the limited leakage design of containment and the low probability of a Design Basis Accident occurring during this time period.
6.1 and 6.2 If the shield building cannot be restored to OPERABLE status within the required Completion Time, the plant must be brought to a MODE in which the LC0 does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 5 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems. SURVEILLANCE
[ SR 3.6.8.1 REQUIREMENTS Verifying that shield building annulus negative pressure is within limit ensures that operation mains within the limit assumed in the containment analysis.
c The 12 hour Frequency of this SR was developed considering operating experience related to shield building annulus pressure variations and pressure instrument drift during the applicable MODES. 1 - emertn) Maintaining shield building OPERABILITY requires verifying one door in the access opening closed. [An access opening may contain one inner and one outer door, or in some cases, shield building access openings are shared such that a shield building barrier may have multiple inner or multiple outer doors. The intent is to not breach the shield building boundary at any time when the shield building boundary is required. This is achieved by maintaining the inner or outer portion of the barrier closed at all times.] However, all shield building access doors are normally kept closed, except when the access opening is being used for entry and exit or when maintenance is being performed on an access opening.Ehe 31 day Frequency of this SR is based on engineering judgment and is considered adequate in view of the other indications of door status that are available to the operator.
< G79e.d- C) WOG STS B 3.6.8-2 Rev. 3.0, 03/31/04 BASES ACTIONS SURVEILLANCE REQUIREMENTS Shield Building (Dual and Ice Condenser)
B 3.6.8 In the event shield building OPERABILITY is not maintained, shield building OPERABILITY must be restored within 24 hours.Twenty-four hours is a reasonable Completion Time considering the limited leakage design of containment and the low probability of a Design Basis Accident occurring during this time period.B.1 and B.2 If the shield building cannot be restored to OPERABLE status within the required Completion Time, the plant must be brought to a MODE in which the LCO does not apply.To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 5 within 36 hours.The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.[SR 3.6.8.1 Verifying that shield building annulus negative pressure is within limit ensures that within the limit assumed in the containment analysis.l!he 12 hour Frequency of this SR was developed considering operating experience related to shield building annulus pressure variations and pressure instrument drift during the applicable SR 3.6.8.2 Maintaining shield building OPERABILITY requires verifying one door in the access opening closed.[An access opening may contain one inner and one outer door, or in some cases, shield building access openings are shared such that a shield building barrier may have mUltiple inner or multiple outer doors.The intent is to not breach the shield building boundary at any time when the shield building boundary is required.This is achieved by maintaining the inner or outer portion of the barrier closed at all times.]However, all shield building access doors are normally kept closed, except when the access opening is being used for entry and exit or when maintenance is being performed on an access opening.Uhe 31 day Frequency of this SR is based on engineering judgment and is considered adequate in view of the other indications of door status that are available to the operator.
WOG STS B 3.6.8-2 Rev.3.0, 03/31/04 Shield Building (Dual and Ice Condenser)
B 3.6.8 BASES SURVEILLANCE REQUIREMENTS (continued)
[SR 3.6.8.3 This SR would give advance indication of gross deterioration of the concrete structural integrity of the shield building.The Frequency Of this SR is the same as that of SR 3.6.1.1.The verification is done during shutdown.]SR 3.6.8.4 The Shield Building Air Cleanup System produces a negative pressure to prevent leakage from the building.SR 3.6.8.4 verifies that the shield building can be rapidly drawn down to[-0.5]inch water gauge in the annulus.This test is used to ensure shield building boundary integrity.
Establishment of this pressure is confirmed by SR 3.6.8.4, which demonstrates that the shield building can be drawn down to[-0.5]inches of vacuum water gauge in the annulus[22]seconds using one Shield Building Air Cleanup System train.The time limit ensures that no significant quantity of radioactive material leaks from the shield building prior to developing the negative pressure.Since this SR is a shield building boundary integrity test, it does not need to be performed with each Shield Building Air Cleanup System train.Uhe Shield Building Air Cleanup System train used for this Surveillance is staggered to ensurethat in addition to the requirements of LCO 3.6.8.4, either train will perform this testJ The primary purpose of this SR is to ensure shield building integrity.
The secondary purpose of this SR is to ensure that the Shield Building Air Cleanup System being tested functions as designed.The inoperability of the Shield Building Air Cleanup System train does not necessarily constitute a failure of this Surveillance relative to the shield.building OPERABILITY.
e 18 month Frequency is based on the need to perform this Surveillance under conditions that apply during a plant outage.REFERENCES WOGSTS None.B 3.6.8-3 Rev.3.0, 03/31/04 Shield Building (Dual and Ice Condenser)
B 3.6.8 BASES SURVEILLANCE REQUIREMENTS (continued)
[SR 3.6.8.3 This SR would give advance indication of gross deterioration of the concrete structural integrity of the shield building.The Frequency*of this SR is the same as that of SR 3.6.1.1.The verification is done during shutdown.]SR 3.6.8.4 The Shield Building Air Cleanup System produces a negative pressure to prevent leakage from the building.SR 3.6.8.4 verifies that the shield building can be rapidly drawn down to[-0.5]inch water gauge in the annulus.This test is used to ensure shield building boundary integrity.
Establishment of this pressure is confirmed by SR 3.6.8.4, which demonstrates that the shield building can be drawn down to[-0.5]inches of vacuum water gauge in the annulus[22]seconds using one Shield Building Air Cleanup System train.The time limit ensures that no significant quantity of radioactive material leaks from the shield building prior to developing the negative pressure.Since this SR is a shield building boundary integrity test, it does not need to be performed with each Shield Building Air Cleanup System train.l1he Shield Building Air Cleanup System train used for this Surveillance is staggered to ensure*that in addition to the requirements of LCO 3.6.8.4, either train will perform this testJ The primary purpose of this SR is to ensure shield building integrity.
The secondary purpose of this SR is to ensure that the Shield Building Air Cleanup System being tested functions as designed.The inoperability of the Shield Building Air Cleanup System train does not necessarily constitute a failure of this Surveillance relative to the shield.building OPERABILITY.
e 18 month Frequency is based on the need to perform this Surveillance under conditions that apply during a plant outage.
VI se yt;a REFERENCES WaG STS None.B 3.6.8-3 Rev.3.0, 03/31/04 HMS (Atmospheric, Ice Condenser, and Dual) B 3.6.9 BASES ACTIONS (continued)
[Both] the [initial] verification [and all subsequent verifications] may be performed as an administrative check, by examining logs or other information to determine the availability of the alternate hydrogen control system. It does not mean to perform the Surveillances needed to demonstrate OPERABILITY of the alternate hydrogen control system. If the ability to perform the hydrogen control function is maintained, continued operation is permitted with two HMS trains inoperable for up to 7 days. Seven days is a reasonable time to allow two HMS trains to be inoperable because the hydrogen control function is maintained and because of the low probability of the occurrence of a LOCA that would generate hydrogen in the amounts capable of exceeding the flammability limit. If an inoperable HMS train cannot be restored to OPERABLE status within the required Completion Time, the plant must be brought to a MODE in which the LC0 does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 6 hours. The allowed Completion Time of 6 hours is reasonable, based on operating experience, to reach MODE 3 from full power conditions in an orderly manner and without challenging plant systems. SURVEILLANCE SR 3.6.9.1 REQUIREMENTS Operating each HMS train for r 15 minutes ensures that each train is OPERABLE and that all associated controls are functioning properly.
It also ensures that blockage, fan and/or motor failure, or excessive vibration can be detected for corrective action.
@e 92 day Frequency is consistent with Inservice Testing Program Surveillance Frequencies, operating experience, the known reliability of the fan motors and controls, and the two train redundancy available.
& c*seTfTJ WOG STS B 3.6.9-4 Rev. 3.0, 03/31/04 HMS (Atmospheric, Ice Condenser, and Dual)B 3.6.9 BASES ACTIONS (continued)
I EWE R'S NOTE The following is to be used if a non-Technical Specification alternate hydrogen control function is used to justify this Condition:
In addition, the alternate hydrogen control system capability must be verified once per 12 hours thereafter to ensure its continued availability.
[Both]the[initial]verification
[and all subsequent verifications]
may be performed as an administrative check, by examining logs or other information to determine the availability of the alternate hydrogen control system.It does not mean to perform the Surveillances needed to demonstrate OPERABILITY of the alternate hydrogen control system.If the ability to perform the hydrogen control function is maintained, continued operation is permitted with two HMS trains inoperable for up to 7 days.Seven days is a reasonable time to allow two HMS trains to be inoperable because the hydrogen control function is maintained and because of the low probability of the occurrence of a LOCA that would generate hydrogen in the amounts capable of exceeding the flammability limit.If an inoperable HMS train cannot be restored to OPERABLE status within the required Completion Time, the plant must be brought to a MODE in which the LCO does not apply.To achieve this status, the plant must be brought to at least MODE 3 within 6 hours.The allowed'Completion Time of 6 hours is reasonable, based on operating experience, to reach MODE 3 from full power conditions in an orderly manner and without challenging plant systems.SURVEILLANCE REQUIREMENTS SR 3.6.9.1 Operating each HMS train for;::=15minutesensures that each train is OPERABLE and that all associated controls are functioning properly.It also ensures that blockage, fan and/or motor failure, or excessive vibration can be detected for corrective action.{fhe 92 day Frequency is consistent with Inservice Testing Program Surveillance Frequencies, operating experience, the known reliability of the fan motors and controls, and the two train redundancy available.--V WOGSTS B 3.6.9-4 Rev.3.0, 03/31/04 HMS (Atmospheric, Ice Condenser, and Dual)
B 3.6.9 BASES -- - SURVEILLANCE REQUIREMENTS (continued)
Verifying that each HMS train flow rate on slow speed is 2 [4000] cfm ensures that each train is capable of maintaining localized hydrogen concentrations below the flammability limit. Ehe [I81 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power. Operating experience has shown that these components usually pass the Surveillance when performed at the
[I81 month Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.
This SR ensures that each HMS train responds properly to a containment cooling actuation signal. The Surveillance verifies that each fan starts on slow speed from the nonoperating condition and that each fan shifts to slow speed from fast operating condition.
Ehe [I81 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power. Operating experience has shown these components usually pass the Surveillance when performed at the
[18] month Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.
REFERENCES
: 1. 10 CFR 50.44.
: 2. 10 CFR 50, Appendix A, GDC 41. 3. Regulatory Guide 1.7, Revision [I]. WOG STS Rev. 3.0, 03/31/04 HMS (Atmospheric, Ice Condenser, and Dual)B 3.6.9 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.6.9.2 Verifying that each HMS train flow rate on slow speed is[4000J cfm ensures that each train is capable of maintaining localized hydrogen concentrations below the flammability limit.@1e[18]month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power.Operating experience has shown that these components usually pass the Surveillance when performed at the[18]month Frequency.
Therefore, the Frequency was concluded to be acceptable from a reliability fi=J'\..It,D e ("*2.,)
SR 3.6.
 
==9.3 REFERENCES==
 
This SR ensures that each HMS train responds properly to a containment cooling actuation signal.The Surveillance verifies that each fan starts on slow speed from the nonoperating condition and that each fan shifts to slow speed from fast operating condition.
tLhe[18J month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if theSurveillancewere performed with the reactor at power.Operating experience has shown these components usually pass the Surveillance when performed at the[18J month Frequency.
Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.1.10 GFR 50.44.;\sz,r 1.2.10 GFR 50, Appendix A, GOG 41.3.Regulatory Guide 1.7, Revision[1J.WOGSTS B 3.6.9-5 Rev.3.0, 03/31/04 HIS (Ice Condenser)
B 3.6.10 BASES ACTIONS (continued)
The unit must be placed in a MODE in which the LC0 does not apply if the HIS subsystem(s) cannot be restored to OPERABLE status within the associated Completion Time. This is done by placing the unit in at least MODE 3 within 6 hours. The allowed Completion Time of 6 hours is reasonable, based on operating experience, to reach MODE 3 from full power conditions in an orderly manner and without challenging plant systems. SURVEILLANCE SR 3.6.10.1 REQUIREMENTS This SR confirms that 2 [32] of 33 hydrogen ignitors can be successfully energized in each train.
The ignitors are simple resistance elements. Therefore, energizing provides assurance of OPERABILITY. The allowance of one inoperable hydrogen ignitor is acceptable because, although one inoperable hydrogen ignitor in a region would compromise redundancy in that region, the containment regions are interconnected so that ignition in one region would cause burning to progress to the others (i.e., there is overlap in each hydrogen ignitor's effectiveness between regions).
Ee Frequency of 92 days has been shown to be acceptable through operating experience.
f -.*, c~xsertz)
This SR confirms that the two inoperable hydrogen ignitors allowed by SR 3.6.10.1 (i.e., one in each train) are not in the same containment region. Ee Frequency of 92 days is acceptable based on the Frequency of SR 3.6.10.1, which provides the information for performF,RGEq Sn~er A more detailed functional test is performed&vwfIS
~~663 to verify system OPERABILITY. Each glow plug is visually examined to ensure that it is clean and that the electrical circuitry is energized.
All ignitors (glow plugs), including normally inaccessible ignitors, are visually checked for a glow to verify that they are energized. Additionally, the surface temperature of each glow plug is measured to be r [1700]"F to demonstrate that a temperature sufficient for ignition is achieved.
Ehe [18] month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the WOG STS B 3.6.10-4 Rev. 3.0.
03/31/04 HIS (Ice Condenser)
B 3.6.10 BASES ACTIONS (continued)
The unit must be placed in a MODE in which the LCO does not apply if the HIS subsystem(s) cannot be restored to OPERABLE status within the associated Completion Time.This is done by placing the unit in at least MODE 3 within 6 hours.The allowed Completion Time of 6 hours is reasonable, based on operating experience, to reach MODE 3 from full power conditions in an orderly manner and without challenging plant systems.SURVEILLANCE SR 3.6.10.1 REQUIREMENTS This SR confirms that;;::[32)of 33 hydrogen ignitors can be successfully energized in each train.The ignitors are simple resistance elements.Therefore, energizing provides assurance of OPERABILITY.
The allowance of one inoperable hydrogen ignitor is acceptable because, although one inoperable hydrogen ignitor in a region would compromise redundancy in that region, the containment regions are interconnected so that ignition in one region would cause burning to progress to the others (i.e., there is overlap in each hydrogen ignitor's effectiveness between regions).[he Frequency of 92 days has been shown to be acceptable through operating experience.
T.Y*)5ev-****
SJ SR 3.6.10.2 This SR confirms that the twoinoperablehydrogen ignitors allowed by SR 3.6.10.1 (i.e., one in each train)are not in the same containment region.[6e Frequency of 92 days is acceptable based on the Frequency of SR 3.6.10.1, which provides the information for tt:!!s..
b f.3:)SR 3.6.10.3 A more detailed functional test is performedtevEifii]jRafil&sect; to verify system OPERABILITY.
Each glow plug is visually examined to ensure that it is clean and that the electrical circuitry;s energized.
All ignitors (glow plugs), including normally inaccessible ignitors, are visually checked for a glow to verify that they are energized.
Additionally, the surface temperature of each glow plug is measured to be;;::[1700rF to demonstrate that a temperature sufficient for ignition is achieved.[he[18)month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the WOG STS B 3.6.10-4 Rev.3.0, 03/31104 HIS (Ice Condenser)
B 3.6.10 BASES SURVEILLANCE REQUIREMENTS (continued) reactor at power. Operating experience has shown that these components usually pass the SR when performed at the [I81 month Frequency, which is based on the refueling cycle. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.
REFERENCES I. 10 CFR 50.44. 2. 10 CFR 50, Appendix A, GDC 41. 3. FSAR, Section [6.2]. WOG STS Rev. 3.0, 03/31/04 HIS (Ice Condenser)
B 3.6.10 BASES SURVEILLANCE REQUIREMENTS (continued) reactor at power.Operating experience has shown that these components usually pass the SR when performed at the[18]month Frequency, which is based on the refueling cycle.Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.
REFERENCES 1.10 CFR 50.44.r-se.r.:..W 2.10 CFR 50, Appendix A, GOC 41.3.FSAR, Section[6.2].WOGSTS B 3.6.10-5 Rev.3.0, 03/31/04 ICS (Atmospheric and Subatmospheric)
B 3.6.1 1 BASES ACTIONS With one ICS train inoperable, the inoperable train must be restored to OPERABLE status within 7 days. The components in this degraded condition are capable of providing 100% of the iodine removal needs after a DBA. The 7 day Completion Time is based on consideration of such factors as: a. ' The availability of the OPERABLE redundant ICS train, b. The fact that, even with no ICS train in operation, almost the same amount of iodine would be removed from the containment atmosphere through absorption by the Containment Spray System, and c. The fact that the Completion Time is adequate to make most repairs.
6.1 and 8.2 If the ICS train cannot be restored to OPERABLE status within the required Completion Time, the plant must be brought to a MODE in which the LC0 does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 5 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner without challenging plant systems.
SURVEILLANCE SR 3.6.1 1 .I REQUIREMENTS Operating each ICS train for r 15 minutes ensures that all trains are OPERABLE and that all associated controls are functioning properly. It also ensures that blockage, fan or motor failure, or excessive vibration can be detected for corrective action. For systems with heaters, operation with the heaters on (automatic heater cycling to maintain temperature) for r 10 continuous hours eliminates moisture on the adsorbers and HEPA filters. Experience from filter testing at operating units indicates that the 10 hour period is adequate for moisture elimination on the adsorbers and HEPA filters. che 31 day Frequency was developed considering the known reliability of fan motors and controls, the two train redundancy available, and the iodine removal capability of the Containment spray System independent
---. of the ---.--.- ICS. 6'- ... A - f-r Ce f t; ?J -.-- WOG STS Rev. 3.0, 03/31/04 ICS (Atmospheric and Subatmospheric)
B 3.6.11 BASES ACTIONS A.1 With one ICS train inoperable, the inoperable train must be restored to OPERABLE status within 7 days.The components in this degraded condition are capable of providing 100%of the iodine removal needs after a DBA.The 7 day Completion Time is based on consideration of such factors as: a."The availability of the OPERABLE redundant ICS train, b.The fact that, even with no rcs train in operation, almost the same amount of iodine would be removed from the containment atmosphere through absorption by the Containment Spray System, and c.The fact that the Completion Time is adequate to make most repairs.B.1 and B.2 If the ICS train cannot be restored to OPERABLE status within the required Completion Time, the plant must be brought to a MODE in which the LCO does not apply.To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 5 within 36 hours.The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner without challenging plant systems.SURVEILLANCE REQUIREMENTS SR 3.6.11.1 Operating each ICS train for15 minutes ensures that all trains are OPERABLE and that all associated controls are functioning properly.It also ensures that blockage, fan or motor failure, or excessive vibration can be detected for corrective action.For systems with heaters, operation with the heaters on (automatic heater cycling to maintain temperature) for10 continuous hours eliminates moisture on the adsorbers and HEPA filters.Experience from filter testing at operating units indicates that the 10 hour period is adequate for moisture elimination on the adsorbers and HEPA filters.[1he 31 day Frequency was developed considering the known reliability of fan motors and controls, the two train redundancy available, and the iodine removal capability of the Containment Spray System independent of the ICS.
__
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y\<":'" C"." r t 7\.._..
WOGSTS B 3.6.11-3 Rev.3.0, 03/31/04 ICS (Atmospheric and Subatmospheric)
B 3.6.1 1 BASES - - SURVEILLANCE REQUIREMENTS (continued)
This SR verifies that the required ICS filter testing is performed in accordance with the Ventilation Filter Testing Program (VFTP). The VFTP includes testing HEPA filter performance, charcoal adsorber efficiency, minimum system flow rate, and the physical properties of the activated charcoal (general use and following specific operations). Specific test frequencies and additional information are discussed in detail in the VFTP. The automatic startup test verifies that both trains of equipment start upon receipt of an actual or simulated test signal.
rhe [I81 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power. Operating experience has shown that these components usually pass the Surveillance when performed at the 118) month Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint. Furthermore, the Frequency was developed considering that the system equipment OPERABILITY is demonstrated
". . - --+ -+" --- ,-. at a 31 day Frequency by SR 3.6.1 1 .I. & +" <x:- :2:> !+?3i'+J The ICS filter bypass dampers are tested to verify OPERABILITY. The dampers are in the bypass position during normal operation and must reposition for accident operation to draw air through the filters.
lfhe [I81 month Frequency is considered to be acceptable based on the damper reliability and design, the mild environmental conditions in the vicinity of the dampers, and the fact that operating experience has shown that the dampers usually pass the Surv 'Ilance when erformed at the [I 81 month Frequency.
] / rC,.do+ -& 6%~ REFERENCES
: 1. 10 CFR 50, Appendix A, GDC 41, GDC 42, and GDC 43. 2. FSAR, Section
[6.5]. 3. Regulatory Guide 1.52, Revision 121. 4. FSAR, Chapter
[15]. WOG STS B 3.6.1 1-4 Rev. 3.0, 03/31/04 ICS (Atmospheric and Subatmospheric)
B 3.6.11 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.6.11.2 This SR verifies that the required ICS filter testing is performed in accordance with the Ventilation Filter Testing Program (VFTP).The VFTP includes testing HEPA filter performance, charcoal adsorber efficiency, minimum system flow rate, and the physical properties of the activated charcoal (general use and following specific operations).
Specific test frequencies and additional information are discussed in detail in the VFTP.SR 3.6.11.3 The automatic startup test verifies that both trains of equipment start upon receipt of an actual or simulated test signal.@e[18]month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power.Operating experience has shown that these components usually pass the Surveillance when performed at the[18]month Frequency.
Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.
Furthermore, the Frequency was developed considering that the system equipment OPERABILITY is demonstrated at a 31 day Frequency by SR 3.6.11.1...".
V..**.,fi,.*'._J:-J[SR 3.6.11.4 The ICS filter bypass dampers are tested to verify OPERABILITY.
The dampers are in the bypass position during normal operation and must reposition for accident operation to draw air through the filters.Uhe[18]month Frequency is considered to be acceptable based on the damper reliability and design, the mild environmental conditions in the vicinity of the dampers, and the fact that operating experience has shown that the dampers usually pass the Surv'llance when erformed at the[18]month Frequency.]
nC" t REFERENCES 1.10 CFR 50, Appendix A, GOC 41, GOC 42, and GOC 43.2.FSAR, Section[6.5].3.Regulatory Guide 1,52, Revision[2].4.FSAR, Chapter[15].WOGSTS B 3.6.11-4 Rev.3.0, 03/31/04 SBACS (Dual and Ice Condenser)
B 3.6.13 BASES SURVEILLANCE SR 3.6.13.1 REQUIREMENTS Operating each SBACS train for 2 15 minutes ensures that all trains are OPERABLE and that all associated controls are functioning properly.
It also ensures that blockage, fan or motor failure, or excessive vibration can be detected for corrective action. For systems with heaters, operation with the heaters on (automatic heater cycling to maintain temperature) for 2 I0 continuous hours eliminates moisture on the adsorbers and HEPA filters. Experience from filter testing at operating units indicates that the 10 hour period is adequat for moisture elimination on the adsorbers and HEPA filters. $e 31 day Frequency was developed in consideration of the known reliability of fan motors and controls, the two train redundancy available, and the iodine removal capability of the Containment splay System. 6 ehSert-3 This SR verifies that the required SBACS filter testing is performed in accordance with the Ventilation Filter Testing Program (VFTP). The VFTP includes testing HEPA filter performance, charcoal adsorber efficiency, minimum system flow rate, and the physical properties of the activated charcoal (general use and following specific operations). Specific test frequencies and additional information are discussed in detail in the VFTP. T e automatic startup ensures that each SBACS train responds properly.
The [I81 month Frequency is based on the need to perform this c" Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power. Operating experience has shown that these components usually pass the Surveillance when performed at the [I 81 month Frequency. Therefore the Frequency was concluded to be acceptable from a reliability standpoint. Furthermore, the SR interval was developed considering that the SBACS equipment OPERABILITY is demonstrated at a 31 day Frequency by SR 3.6.1 3.1. f -.,*- Grrn WOG STS B 3.6.1 3-4 Rev. 3.0, 03/31/04 SBACS (Dual and Ice Condenser)
B 3.6.13 BASES SURVEILLANCE SR 3.6.13.1 REQUIREMENTS Operating each SBACS train for:?: 15 minutes ensures that all trains are OPERABLE and that all associated controls are functioning properly.It also ensures that blockage, fan or motor failure, or excessive vibration can be detected for corrective action.Forsystems with heaters, operation with the heaters on (automatic heater cycling to maintain temperature) for:?: 10 continuous hours eliminates moisture on the adsorbers and HEPA filters.Experience from filter testing at operating units indicates that the 10 hour period is for moisture elimination on the adsorbers and HEPA filters. 31 day Frequency was developed in consideration of the known reliability of fan motors and controls, the two train redundancy available, and the iodine removal capability of the Containment Spray System. f3)Ihser 2.SR 3.6.13.2 This SR verifies that the required SBACS filter testing is performed in accordance with the Ventilation Filter Testing Program (VFTP).The VFTP includes testing HEPA filter performance, charcoal adsorber efficiency, minimum system flow rate, and the physical properties of the activated charcoal (general use and following specific operations).
Specific test frequencies and additional information are discussed in detail in the VFTP.SR 3.6.13.3 ,Ibe automatic startup ensures that each SBACS train responds properly.llhe[18}month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power.Operating experience has shown that these components usually pass the Surveillance when performed at the[18}month Frequency.
Therefore the Frequency was concluded to be acceptable from a reliability standpoint.
Furthermore, the SR interval was developed considering that the SBACS equipment OPERABILITY is demonstrated at a 31 day Frequency by SR 3.6.13.1.L.Of3d 2..WOGSTS B 3.6.13-4 Rev.3.0, 03/31/04 SBACS (Dual and Ice Condenser)
B 3.6.13 BASES SURVEILLANCE REQUIREMENTS (continued)
[SR 3.6.13.4 The SBACS filter bypass dampers are tested to verify OPERABILITY.
The dampers are in the bypass position during normal operation and must reposition for accident operation to draw air through the filters.
@e [I81 month Frequency is considered to be acceptable based on damper reliability and design, mild environmental conditions in the vicinity of the dampers, and the fact that operating experience has shown that the dampers usually pass the Surveillance when performed at the [I81 month Frequency.
] --*-- The proper functioning of the fans, dampers, filters, adsorbers, etc., as a system is verified by the ability of each train to produce the required system flow rate.
che [I81 month Frequency on a STAGGERED TEST BASIS is consistent with Regulatory Guide I .52 (Ref. 4) guidance for functional testing.
<-----.-anS'2>
REFERENCES
: 1. 10 CFR 50, Appendix A, GDC 41. 2. FSAR, Section
[6.5]. 3. FSAR, Chapter [15]. 4. Regulatory Guide 1 S2, Revision [Z]. WOG STS Rev. 3.0, 03/31/04 SBACS (Dual and Ice Condenser)
B 3.6.13 BASES SURVEILLANCE REQUIREMENTS (continued)
[SR 3.6.13.4 The SBACS filter bypass dampers are tested to verify OPERABILITY.
The dampers are in the bypass position during normal operation and must reposition for accident operation to draw air through the filters.&sect;e[18]month Frequency is considered to be acceptable based on damper reliability and design, mild environmental conditions in the vicinity of the dampers, and the fact that operating experience has shown that the dampers usually pass the Surveillance when performed at the[18]month FreqUencYt
__
SR 3.6.13.5 The proper functioning of the fans, dampers, filters, adsorbers, etc., as a system is verified by the ability of each train to produce the required system flow rate.[[he[18]month Frequencyona STAGGERED TEST BASIS is consistent with Regulatory Guide 1.52 (Ref.4)guidance for functional testing...(----U n Se:;::r--:0 REFERENCES WOGSTS 1.10 CFR 50, Appendix A, GDC 41.2.FSAR, Section[6.5].3.FSAR, Chapter[15].4.Regulatory Guide 1.52.Revision[2].B 3.6.13-5 Rev.3.0, 03/31/04 ARS (Ice Condenser)
B 3.6.14 BASES ACTIONS (continued)
B.l and B.2 If the ARS train cannot be restored to OPERABLE status within the required Completion Time, the plant must be brought to a MODE in which the LC0 does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 5 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems. SURVEILLANCE SR 3.6.14.1 REQUIREMENTS Verifying that each ARS fan starts on an actual or simulated actuation signal, after a delay 2 [9.0] minutes and S [I 1 .O] minutes, and operates for 2 15 minutes is sufficient to ensure that all fans are OPERABLE and that all associated controls and time delays are functioning properly. It also ensures that blockage, fan and/or motor failure, or excessive vibration can be detected for corrective action.che
[92] day Frequency was developed considering the known reliability of fan motors and controls and the two train redundancy available.
+ 7.zFzzEa Verifying ARS fan motor current to be at rated speed with the return air dampers closed confirms one operating condition of the fan. This test is indicative of overall fan motor performance. Such inservice tests confirm component OPERABILITY, trend performance and detect incipient failures by indicating abnormal performance.
che Frequency of 92 days conforms with the testing requirements for similar ESF equipment and considers the known reliability of fan motors and controls and the two train redundancy available. Verifying the OPERABILITY of the return air damper provides assurance that the proper flow path will exist when the fan is started.
By applyin the correct counterweight, the damper operation can be confirmed.
&e Frequency of 92 days was developed considering the importance of the dampers, their location, physical environment, and probability of failure. Operating experience has also shown this Frequency to be acceptable.- (fZZ+Ql WOG STS B 3.6.14-4 Rev. 3.0, 03/31/04 ARS (Ice Condenser)
B 3.6.14 BASES ACTIONS (continued)
B.1 and B.2 If the ARS train cannot be restored to OPERABLE status within the required Completion Time.the plant must be brought to a MODE in which the LCO does not apply.To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 5 within 36 hours.The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.SURVEILLANCE REQUIREMENTS SR 3.6.14.1 Verifying that each ARS fan starts on an actual or simulated actuation signal, after a delay;:::[9.0]minutes and S[11.0]minutes, and operates for;::: 15 minutes is sufficient to ensure that all fans are OPERABLE and that all associated controls and time delays are functioning properly.It also ensures that blockage, fan andlor motor failure, or excessive vibration can be detected for corrective action.U:he[92]day Frequency wasdevelopedconsidering the known reliability of fan motors and controls and the two train redundancy available.
<:----c:r:.hSe r f2)SR 3.6.14.2 Verifying ARS fan motor current to be at rated speed with the return air dampers closed confirms one operating condition of the fan.This test is indicative of overall fan motor performance.
Such inservice tests confirm component OPERABILITY, trend performance and detect incipient failures by indicating abnormal performance.
fue Frequency of 92 days conforms with the testing requirements for similar ESF equipment and considers the known reliability of fan motors and controls and the two train redundancy SR 3.6.14.3 Verifying the OPERABILITY of the return air damper provides assurance that the proper flow path will exist when the fan is started.By the correct counterweight, the damper operation can be confirmed.l!.he Frequency of 92 days was developed considering the importance of the dampers, their location, physical environment, and probability of failure.Operating experience has also shown this Frequency to be WOG STS B 3.6.14-4 Rev.3.0, 03/31/04 ARS (Ice Condenser)
B 3.6.14 BASES SURVEILLANCE REQUIREMENTS (continued)
[ SR 3.6.14.4 Verifying the OPERABILITY of the motor operated valve in the Hydrogen Skimmer System hydrogen collection header to the lower containment compartment provides assurance that the proper flow path will exist when the valve receives an actuation signal. This Surveillance is not required for valves that are locked, sealed, or otherwise secured in the required position under administrative controls. This Surveillance o confirms that the time delay to open is within specified tolerances.
r' The 92 day Frequency was developed considering the known reliability of the motor operated valves and controls and the two train redundancy available.
f Operating experience has also shown this Frequency to be acceptable.
] 7 REFERENCES 1 FSAR, Section
[6.2]. 2. 10 CFR 50, Appendix K. WOG STS Rev. 3.0, 03/31/04 ARS (Ice Condenser)
B 3.6.14 BASES SURVEILLANCE REQUIREMENTS (continued)
[SR 3.6.14.4 Verifying the OPERABILITY of the motor operated valve in the Hydrogen Skimmer System hydrogen collection header to the lower containment compartment provides assurance that the proper flow path will exist when the valve receives an actuation signal.This Surveillance is not required for valves that are locked, sealed, or otherwise secured in the required position under administrative controls.This Surveiliance,.sLso confirms that the time delay to open is within specified tolerancesllhe 92 day Frequencywasdeveloped considering the known reliability of the motoroperatedvalves and controls and the two train redundancy available.
..[)Operating experience has also shown this Frequency to be acceptable.]
_I REFERENCES 1.FSAR, Section[6.2].
2.10 CFR 50, Appendix K.WOGSTS B 3.6.14-5 Rev.3.0, 03/31/04 Ice Bed (Ice Condenser)
B 3.6.15 BASES - - -- - ACTIONS (continued)
B.l and B.2 If the ice bed cannot be restored to OPERABLE status within the required Completion Time, the plant must be brought to a MODE in which the LC0 does not apply.
To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 5 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.
SURVEILLANCE SR 3.6.15.1 REQUIREMENTS Verifying that the maximum temperature of the ic bed is S [27I0F ensures that the ice is kept well below the melting point. the 112 hour Frequency was based on operating experience, which confirmed that, due to the large mass of stored ice, it is not possible for the ice bed temperature to degrade significantly within a 12 hour period and was also based on assessing the proximity of the LC0 limit to the melting temperature.
Furthermore, the 12 hour Frequency is considered adequate in view of indications in the control room, including the alarm, to alert the operator to an abnormal ice bed temperature condition. This SR may be satisfied by use of the Ice Bed
~emperature Monitoring System. " 'FZ~ - Ice mass determination methodology is designed to verify the total as- found (pre-maintenance) mass of ice in the ice bed, and the appropriate distribution of that mass, using a random sampling of individual baskets. The random sample will include at least 30 baskets from each of three defined Radial Zones (at least 90 baskets total). Radial Zone A consists of baskets located in rows [7, 8, and 91 (innermost rows adjacent to the crane wall), Radial Zone B consists of baskets located in rows [4, 5, and 61 (middle rows of the ice bed), and Radial Zone C consists of baskets located in rows [I, 2, and 31 (outermost rows adjacent to the containment vessel).
The Radial Zones chosen include the row groupings nearest the inside and outside walls of the ice bed and the middle rows of the ice bed. These groupings facilitate the statistical sampling plan by creating sub- populations of ice baskets that have similar mean mass and sublimation characteristics.
WOG STS B 3.6.1 5-5 Rev. 3.1, 12/01/05 lee Bed (Ice Condenser)
B 3.6.15 BASES ACTIONS (continued)
B.1 and B.2 If the ice bed cannot be restored to OPERABLE status within the required Completion Time, the plant must be brought to a MODE in which the LCO does not apply.To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 5 within 36 hours.The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.SURVEILLANCE SR 3.6.15.1 REQUIREMENTS Verifying that the maximum temperature of thebed is s;[27rF ensures that the ice is kept well below the melting point.Uhe 12 hour Frequency was based on operating experience, which confirmed that, due to the large mass of stored ice, it is not possible for the ice bed temperature to degrade significantly within a 12 hour period and was also based on assessing the proximity of the LCO limit to the melting temperature.
Furthermore, the 12 hour Frequency is considered adequate in view of indications in the control room, including the alarm, to alert the operator to an abnormal ice bed temperature condition.
This SR may be satisfied by use of the Ice Bed Temperature Monitoring
_rQe,xt"6J SR 3.6.15.2 Ice mass determination methodology is designed to verify the totalfound (pre-maintenance) mass of ice in the ice bed, and the appropriate distribution of that mass, using a random sampling of individual baskets.The random sample will include at least 30 baskets from each of three defined Radial Zones (at least 90 baskets total).Radial Zone A consists of baskets located in rows[7, 8, and 9J (innermost rows adjacent to the crane wall), Radial Zone B consists of baskets located in rows[4, 5, and 6J (middle rows of the ice bed), and Radial Zone C consists of baskets located in rows[1, 2, and 3J (outermost rows adjacent to the containment vessel).The Radial Zones chosen include the row groupings nearest the inside and outside walls of the ice bed and the middle rows of the ice bed.These groupings facilitate the statistical sampling plan by creatingpopulations of ice baskets that have similar mean mass and sublimation characteristics.
WOGSTS B 3.6.15-5 Rev.3.1,12/01/05 Ice Bed (Ice Condenser)
B 3.6.15 BASES SURVEILLANCE REQUIREMENTS (continued) Methodology for determining sample ice basket mass will be either by direct lifting or by alternative techniques.
Any method chosen will include procedural allowances for the accuracy of the method used. [The number of sample baskets in any Radial Zone may be increased one by adding 20 or more randomly selected baskets to verify the total mass of that Radial Zone.] In the event the mass of a selected basket in a sample population (initial or expanded) cannot be determined by any available means (e.g., due to surface ice accumulation or obstruction), a randomly selected representative alternate basket may be used to replace the original selection in that sample population. If employed, the representative alternate must meet the following criteria:
: a. Alternate selection must be from the same bay-Zone (i.e., same bay, same Radial Zone) as the original selection, and
: b. Alternate selection cannot be a repeated selection (original or alternate) in the current Surveillance, and cannot have been used as an analyzed alternate selection in the three most recent Surveillances. The complete basis for the methodology used in establishing the 95% confidence level in the total ice bed mass is documented in Reference 4 and approved in Reference
: 5. The total ice mass and individual Radial Zone ice mass requirements defined in this Surveillance, and the minimum ice mass per basket requirement defined by SR 3.6.15.3, are the minimum requirements for OPERABILITY. Additional ice mass beyond the SRs is maintained to address sublimation. This sublimation allowance is generally applied to baskets in each Radial Zone, as appropriate, at the beginning of an operating cycle to ensure sufficient ice is available at the end of the operating cycle for the ice condenser to perform its intended design function.
Ge Frequency of 18 months was based on ice storage tests, and the typical sublimation allowance maintained in the ice mass over and above the minimum ice mass assumed in the safety analyses.
Operating and maintenance experience has verified that, with the 18 month Frequency, the minimum mass and distribution requirements in the ice bed are maintained.
6 .--szt-z)
WOG STS B 3.6.15-6 Rev. 3.1, 12/01/05 Ice Bed (Ice Condenser)
B 3.6.15 BASES SURVEILLANCEREQUIREMENTS(continued)
Methodology for determining sample ice basket mass will be either by direct lifting or by alternative techniques.
Any method chosen will include procedural allowances for the accuracy of the method used.[The number of sample baskets in any RadialZonemay be increased one by adding 20 or more randomly selected baskets to verify the total mass of that Radial Zone.]In the event the mass of a selected basket in a sample population (initial or expanded)cannot be determined by any available means (e.g., due to surface ice accumulation or obstruction), a randomly selected representative alternate basket may be used to replace the original selection in that sample population.
If employed, the representative alternate must meet the following criteria: a.Alternate selection must be from the same bay-Zone (i.e., same bay, same Radial Zone)as the original selection, and b.Alternate selection cannot be a repeated selection (original or alternate) in the current Surveillance, and cannot have been used as an analyzed alternate selection in the three most recent Surveillances.
The complete basis for the methodology used in establishing the 95%confidence level in the total ice bed mass is documented in Reference 4 and approved in Reference 5.The total ice mass and individual Radial Zone ice mass requirements defined in this Surveillance, and the minimum ice mass per basket requirement defined by SR 3.6.15.3, are the minimum requirements for OPERABILITY.
Additional ice mass beyond the SRs is maintained to address sublimation.
Thissublimationallowance is generally applied to baskets in each Radial Zone, as appropriate, at the beginning of an operating cycle to ensure sufficient ice is available at the end of the operating cycle for the ice condenser to perform its intended design function.\I;e Frequency of 18 months was based on ice storage tests, and the typical sublimation allowance maintained in the ice mass over and above the minimum ice mass assumed in the safety analyses.Operating and maintenance experience has verified that, with the 18 month Frequency, the minimum mass and distribution requirements in the ice bed are maintained.
(..(inSe-rE-i)
WOGSTS B 3.6.15-6 Rev.3.1,12/01/05 Ice Bed (Ice Cbndenser)
B 3.6.15 BASES SURVEILLANCE REQUIREMENTS (continued) Verifying the chemical composition of the stored ice ensures that the stored ice has a boron concentration 2 [1800] ppm and 5 [2000] ppm as sodium tetraborate and a high pH, 2 [9.0] and I(9.51, in order to meet the requirement for borated water when the melted ice is used in the ECCS recirculation mode of operation. Additionally, the minimum boron concentration value is used to assure reactor subcriticality in a post LOCA environment, while the maximum boron concentration is used as the bounding value in the hot leg switchover timing calculation (Ref. 3). This is accomplished by obtaining at least 24 ice samples. Each sample is taken approximately one foot from the top of the ice of each randomly selected ice basket in each ice condenser bay.
The SR is modified by a Note that allows the boron concentration and pH value obtained from averaging the individual samples' analysis results to satisfy the requirements of the SR. If either the average boron concentration or average pH value is outside their prescribed limit, then entry into Condition A is required. Sodium tetraborate has been proven effective in maintaining the boron content for long storage periods, and it also enhances the ability of the solution to remove and retain fission product iodine. The high pH is required to enhance the effectiveness of the ice and the melted ice in removing iodine from the containment atmosphere.
This pH range also minimizes the occurrence of chloride and caustic stress corrosion on mechanical systems and components exposed to ECCS and Containment Spray System fluids in the recirculation mode of operation.
Ehe Frequency of 1543 months is intended to be consistent with the expected length of three fuel cycles, and was developed considering these facts: a. Long term ice storage tests have determined that the chemical composition of the stored ice is extremely stable, b. There are no normal operating mechanisms that decrease the boron concentration of the stored ice, and pH remains within a 9.0-9.5 range when boron concentrations are above approximately 1200 ppm, c. Operating experience has demonstrated that meeting the boron concentration and pH requirements has never been a problem, and d. Someone would have to enter the containment to take the sample, and, if the unit is at power, that person would receive a radiation dose. +- -----+-- 6nse r t iJ WOG STS Rev. 3.1, 12/01/05 Ice Bed (Ice C6ndenser)
B 3.6.15 BASES SURVEILLANCE REQUIREMENTS
{continued}
SR 3.6.15.5 Verifying the chemical composition of the stored ice ensures that the stored ice has a boron concentration;:?;
[1800]ppm and:s;[2000]ppm as sodium tetra borate and a high pH,;:?;[9.0]and s;[9.5], in order to meet the requirement for borated water when the melted ice is used in the ECCS recirculation mode of operation.
Additionally, the minimum boron concentration value is used to assure reactor subcriticality in a post LOCA environment, while the maximum boron concentration is used as the bounding value in the hot leg switchover timing calculation (Ref.3).This is accomplished by obtaining at least 24 ice samples.Each sample is taken approximately one foot fromthetop of the ice of each randomly selected ice basket in each ice condenser bay.The SR is modified by a Note that allows the boron concentration and pH value obtained from averaging the individual samples'analysis results to satisfy the requirements of the SR.If either the average boron concentration or average pH value is outside their prescribed limit, then entry into Condition A is required.Sodium tetra borate has been proven effective in maintaining the boron content for long storage periods, and it also enhances the ability of the solution to remove and retain fission product iodine.The high pH is required to enhance the effectiveness of the ice and the melted ice in removing iodine from the containment atmosphere.
This pH range also minimizes the occurrence of chloride and caustic stress corrosion on mechanical systems and components exposed to ECCS and Containment Spray System fluids in the recirculation mode of operation.lIhe Frequency of[54J months is intended to be consistent with the expected length of three fuel cycles, and was developed considering these facts: a.Long term ice storage tests have determined that the chemical composition of the stored ice is extremely stable, b.There are no normal operating mechanisms that decrease the boron concentration of the stored ice, and pH remains within a 9.0-9.5 range when boron concentrations are above approximately 1200 ppm, c.Operating experience has demonstrated that meeting the boron concentration and pH requirements has never been a problem, and d.Someone would have to enter the containment to take the sample.and, if the unit is at power, that person would receive a radiation dose.
WOGSTS B 3.6.15-9 Rev.3.1,12/01/05 Ice Bed (Ice Condenser)
B 3.6.15 BASES SURVEILLANCE REQUIREMENTS (continued)
This SR ensures that a representative sampling of ice baskets, which are relatively thin walled, perforated cylinders, have not been degraded by wear, cracks, corrosion, or other damage.
The SR is designed around a full-length inspection of a sample of baskets, and is intended to monitor the effect of the ice condenser environment on ice baskets. The groupings defined in the SR (two baskets in each azimuthal third of the ice bed) ensure that the sampling of baskets is reasonably distributed.@he Frequency of 40 months for a visual inspection of the structural soundness of the ice baskets is based on engineering judgment and considers such factors as the thickness of the basket walls relative to corrosion rates expected in their service environment and the results of the long term ice storage testing.
+ yz-zzi~ This SR ensures that initial ice fill and any subsequent ice additions meet the boron concentration and pH requirements of SR 3.6.15.5.
The SR is modified by a Note that allows the chemical analysis to be performed on either the liquid or resulting ice of each sodium tetraborate solution prepared.
If ice is obtained from offsite sources, then chemical analysis data must be obtained for the ice supplied.
REFERENCES
: 1. FSAR, Section
[6.2]. 2. 10 CFR 50, Appendix K. 3. [ Westinghouse letter, WAT-D-10686, "Upper Limit Ice Boron Concentration In Safety Analysis."]
: 4. Topical Report ICUG-001, "Application of the Active Ice Mass Management (AIMM) Concept to the Ice Condenser Ice Mass Technical Specifications," Revision 3, September 2003.
: 5. NRC Letter dated September 7 1, 2003, "Safety Evaluation for Ice Condenser Utility Group Topical Report No. ICUG-001, Revision 2 RE: Application of the Active Ice Mass Management Concept to the Ice Condenser Ice Mass Technical Specification (TAC No. MB3379)." WOG STS Rev. 3.1, 12/01/05 Ice Bed (Ice Condenser)
B 3.6.15 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.6.15.6 This SR ensures that a representative sampling of ice baskets, which are relatively thin walled, perforated cylinders, have not been degraded by wear, cracks, corrosion, or other damage.The SR is designed around a full-length inspection of a sample of baskets, and is intended to monitor the effect of the ice condenser environment on ice baskets.The groupings defined in the SR (two baskets in each azimuthal third of the ice bed)ensure that the sampling of baskets is reasonably distributed.[fhe Frequency of 40 months for a visual inspection of the structural soundness of the ice baskets is based on engineering judgment and considers such factors as the thickness of the basket walls relative to corrosion rates expected in their service environment and the results of the long term ice storage testing.'f'"""-Qa-[g)t X"ser-2 SR 3.6.15.7 This SR ensures that initial ice fill and any subsequent ice additions meet the boron concentration and pH requirements of SR 3.6.15.5.The SR is modified by a Note that allows the chemical analysis to be performed on either the liquid or resulting ice of each sodium tetra borate solution prepared.If ice is obtained from offsite sources, then chemical analysis data must be obtained for the ice supplied.REFERENCES 1.FSAR, Section[6.2].2.10 CFR 50, Appendix K.3.[Westinghouse letter, WAT-D-10686,"Upper Limit Ice Boron Concentration In Safety Analysis.")
4.Topical Report ICUG-001,"Application of the Active Ice Mass Management (AIMM)Concept to the Ice Condenser Ice Mass Technical Specifications," Revision 3, September 2003.5.NRC Letter dated September 11, 2003,"Safety Evaluation for Ice Condenser Utility Group Topical Report No.ICUG-001, Revision 2 RE: Application of the Active Ice Mass Management Concept to the Ice Condenser Ice Mass Technical Specification (TAC No.MB3379)." WOGSTS B3.6.15-10 Rev.3.1,12/01/05 Ice Condenser Doors (Ice Condenser)
B 3.6.16 BASES SURVEILLANCE SR 3.6.16.1 REQUIREMENTS Verifying, by means of the Inlet Door Position Monitoring System, that the inlet doors are in their closed positions makes the operator aware of an inadvertent opening of one or more doors.
che Frequency of 12 hours ensures that operators on each shift are aware of the status of the doors.
*" lll,-...--.,-
SR 3.6.16.2 Verifying, by visual inspection, that each intermediate deck door is closed and not impaired by ice, frost, or debris provides assurance that the intermediate deck doors (which form the floor of the upper plenum where frequent maintenance on the ice bed is performed) have not been left open or obstructed.
@e Frequency of 7 days is based on engineering judgment and takes into consideration such factors as the frequency of entry into the intermediate ice condenser deck, the time required for significant frost buildup, and the probability that a DBA will occur.
+--, Verifying, by visual inspection, that the ice condenser inlet doors are not impaired by ice, frost, or debris provides assurance that the doors are free to open in the event of a DBA. Eor this unit, the Frequency of
[18] months [3 months during the first year after receipt of license] is based on door design, which does not allow water condensation to freeze, and operating experience, which indicates that the inlet doors very rarely fail to meet their SR acceptance criteria. Because of high radiation in the vicinity of the inlet doors during power operation, this Surveillance is normally performed during a shutdown.
yzz7l Verifying the opening torque of the inlet doors provides assurance that no doors have become stuck in the closed position.
The value of [675 in-lb is based on the design opening pressure on the doors of 1.0 lb/ft2. For t this unit, the Frequency of [I81 months [3 months during the first year after receipt of license] is based on the passive nature of the closing mechanism (i.e., once adjusted, there are no known factors that would change the setting, except possibly a buildup of ice; ice buildup is not WOG STS B 3.6.16-6 Rev. 3.0, 03/31/04 BASES SURVEILLANCE REQUIREMENTS Ice Condenser Doors (Ice Condenser)
B 3.6.16 SR 3.6.16.1 Verifying, by means of the Inlet Door Position Monitoring System, that the inlet doors are in their closed positions makes the operator aware of an inadvertent opening of one or more doors.LEbe Frequency of 12 hours.ensures that operators on each shift are aware of the status of the d...
..
,.-r-v C': e"**FJ I\....;>.r-'"<...
SR 3.6.16.2 Verifying, by visual inspection, that each intermediate deck door is closed and not impaired by ice, frost, or debris provides assurance that the intermediate deck doors (which form the floor of the upper plenum where frequent maintenance on the ice bed is performed) have not been left open or obstructed.
\!be Frequency of 7 days is based on engineering judgment and takes into consideration such factors as the frequency of entry into the intermediate ice condenser deck, the time required for significant frost buildup, and the probability that a DBA will occur.SR 3.6.16.3 Verifying, by visual inspection, that the ice condenser inlet doors are not impaired by ice, frost, or debris provides assurance that the doors are free to open in the event of a DBA.[&#xa3;9r this unit, the Frequency of[18]months[3 months during the first year after receipt of license]is based on door design, which does not allow water condensation to freeze, and operating experience, which indicates that the inlet doors very rarely fail to meet their SR acceptance criteria.Because of high radiation in the vicinity of the inlet doors during power operation, this Surveillance is normally performed during a i)SR 3.6.16.4 Verifying the opening torque of the inlet doors provides assurance that no doors have become stuck in the closed position.The value of[675,L.in-lb is based on the design opening pressure on the doors of 1.0 Ib/fe.l&#xa3;or this unit, the Frequency of[18]months[3 months during the first year after receipt of license]is based on the passive nature of the closing mechanism (i.e., once adjusted, there are no known factors that would change the setting, except possibly a buildup of ice;ice buildup is not WOGSTS B 3.6.16-6 Rev.3.0, 03/31/04 Ice Condenser Doors (Ice Condenser)
B 3.6.16 BASES SURVEILLANCE REQUIREMENTS (continued) likely, however, because of the door design, which does not allow water condensation to freeze). Operating experience indicates that the inlet doors usually meet their SR acceptance criteria. Because of high radiation in the vicinity of the inlet doors during power operation, this Surveillance is normally performed during a shutdown.
% nserq The torque test Surveillance ensures that the inlet doors have not developed excessive friction and that the return springs are producing a door return torque within limits. The torque test consists of the following: 1. Verify that the torque, T(OPEN), required to cause opening motion at the [401&deg; open position is 5 [I951 in-lb, 2. Verify that the torque, T(CLOSE), required to hold the door stationary (i.e., keep it from closing) at the [40Io open position is 1 [78] in-lb, and 3. Calculate the frictional torque, T(FRICT) = 0.5 {T(OPEN) - T(CLOSE)), and verify that the T(FRICT) is 5 [4O] in-lb. The purpose of the friction and return torque Specifications is to ensure that, in the event of a small break LOCA or SLB, all of the 24 door pairs open uniformly. This assures that, during the initial blowdown phase, the steam and water mixture entering the lower compartment does not pass through part of the ice ndenser, depleting the ice there, while bypassing the ice in other bays. f' The Frequency of [I81 months 13 months during the first year after receipt of license] is based on the passive nature of the closing mechanism (i.e., once adjusted, there are no known factors that would change the setting, except possibly a buildup of ice; ice buildup is not likely, however, because of the door design, which does not allow water condensation to freeze). Operating experience indicates that the inlet doors very rarely fail to meet their SR acceptance criteria. Because of high radiation in the vicinity of the inlet doors during power operation, this Surveillance is normally performed during a shutdown.
WOG STS B 3.6.16-7 Rev. 3.0, 03/31/04 Ice Condenser Doors (Ice Condenser)
B 3.6.16 BASES SURVEILLANCE REQUIREMENTS (continued) likely, however, because of the door design, which does not allow water condensation to freeze).Operating experience indicates that the inlet doors usually meet their SR acceptance criteria.Because of high radiation in the vicinity of the inlet doors during power operation, this Surveillance is normally performed during a shutdown.ID InSet"" 7_SR 3.6.16.5 The torque test Surveillance ensures that the inlet doors have not developed excessive friction and that the return springs are producing a door return torque within limits.The torque test consists of the following:
1.Verify that the torque, T(OPEN), required to cause opening motion at the[40r open position is::;[195]in-Ib, 2.Verify that the torque, T(CLOSE), reqUired to hold the door stationary (i.e., keepitfrom closing)at the[40]&deg;open position is[78J in-lb, and 3.Calculate the frictional torque, T(FRICT)=0.5{T(OPEN)T(CLOSE)}, and verify that the T(FRICT)is::;[40]in-lb.The purpose of the friction and return torque Specifications is to ensure that, in the event of a small break LOCA or SLB, all of the 24 door pairs open uniformly.
This assures that, during the initial blowdown phase, the steam and water mixture entering the lower compartment does not pass through part of the ice,..condenser, depleting the ice there, while bypassing the ice in other bays.\.Itle Frequency of[18]months[3 months during the first year after receipt of license]is based on the passive nature of the closing mechanism (i.e., onceadjusted,there are noknownfactors that would change the setting, except possibly a buildup of ice;ice buildup is not likely, however, because of the door design, which does not allow water condensation to freeze).Operating experience indicates that the inlet doors very rarely fail to meet their SR acceptance criteria.Because of high radiation in the vicinity of the inlet doors during power operation, this Surveillance is normally performed during a WOG STS B 3.6.16-7 Rev.3.0, 03/31/04 Ice Condenser Doors (Ice Condenser)
B 3.6.16 BASES SURVEILLANCE REQUIREMENTS (continued)
Verifying the OPERABILITY of the intermediate deck doors provides assurance that the intermediate deck doors are free to open in the event of a DBA. The verification consists of visually inspecting the intermediate doors for structural deterioration, verifying free movement of the vent assemblies, and ascertaining free movement of each door when lifted with the applicable force shown below:
Door - Liftinq Force a. Adjacent to crane wall < 37.4 Ib b. Paired with door adjacent to crane wall 5 33.8 1b c. Adjacent to containment wall 5 31.8 1b d. Paired with door adjacent to containment wall 5 31.0 Ib The 18 month Frequency
[3 months during the first year after receipt of b- ~cense] is based on the passive design of the intermediate deck doors, the frequency of personnel entry into the intermediate deck, and the fact that SR 3.6.16.2 confirms on a 7 day Frequency that the doors are not impaired by ice, frost, or debris, which are ways a door would fail the opening foice test (i.e., by sticking or from incieased door weight).@@>
WC"*C. Verifying, by visual inspection, that the top deck doors are in place and not obstructed provides assurance that the doors are performing their function of keeping warm air out of the ice condenser during normal operation, and would not be obstructed if called upon to open in response to a DBA. @e Frequency of 92 days is based on engineering judgment, which considered such factors as the following:
: a. The relative inaccessibility and lack of traffic in the vicinity of the doors make it unlikely that a door would be inadvertently left open, b. Excessive air leakage would be detected by temperature monitoring in the ice condenser, and WOG STS B 3.6.16-8 Rev. 3.0, 03/31/04 Ice Condenser Doors (Ice Condenser)
B 3.6.16 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.6.16.6 Verifying the OPERABILITY of the intermediate deck doors provides assurance that the intermediate deck doors are free to open in the event of a DBA.The verification consists ofvisuallyinspecting the intermediate doors for structural deterioration, verifying free movement of the vent assemblies, and ascertaining free movement of each door when lifted with the applicable force shown below: Door Lifting Force a.Adjacent to crane wall<37.4lb b.Paired with door adjacent to crane wall:$33.81b c.Adjacent to containment wall:$31.81b d.Paired with door adjacent to containment wall:$31.01b fThe 18 month Frequency[3 months during the first year after receipt of is based on the passive design of the intermediate deck doors, the frequency of personnel entry into the intermediate deck, and the fact that SR 3.6.16.2 confirms ona7 day Frequency that the doors are not impaired by ice, frost, or debris, which are ways a door would fail the opening force test (i.e.*by sticking orfromincreased door SR 3.6.16.7 Verifying, by visual inspection, that the top deck doors are in place and not obstructed provides assurance that the doors are performing their function of keeping warm air out of the ice condenser during normal operation, and would not be obstructed if called upon to open in response to a DBA.[be Frequency of 92 days is based on engineering judgment, which considered such factors as the fol/owing:
a.The relative inaccessibility and lack of traffic in the vicinity of the doors make it unlikely that a door would be inadvertently left open, b.Excessive air leakage would be detected by temperature monitoring in the ice condenser, and WOGSTS B 3.6.16-8 Rev.3.0, 03/31/04 Ice Condenser Doors (Ice Condenser)
B 3.6.16 BASES SURVEILLANCE REQUIREMENTS (continued)
: c. The light construction of the doors would ensure that, in the event of a DBA, air and gases passing through the ice condenser would find a flow path, even if a door were obstructed.
6 +-*.m+-,-q--s-w,3--
REFERENCES
: 1. FSAR, Chapter [I 51. 2. 10 CFR 50, Appendix K. WOG STS Rev. 3.0, 03/31/04 Ice Condenser Doors (Ice Condenser)
B 3.6.16 BASES SURVEILLANCE REQUIREMENTS (continued) c.The light construction of the doors would ensure that, in the event of a DBA, air and gases passing through the ice condenser would find a._----:-flow path, even if a door were obstructed.
{..__.....__'"__REFERENCES 1.FSAR, Chapter[15].2.10 CFR 50, Appendix K.WOGSTS B 3.6.16-9 Rev.3.0.03/31/04 Divider Barrier Integrity (Ice Condenser)
B 3.6.17 BASES ACTIONS (continued)
C.l and C.2 If divider barrier integrity cannot be restored to OPERABLE status within the required Completion Time, the plant must be brought to a MODE in which the LC0 does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 5 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems. SURVEILLANCE SR 3.6.17.1 REQUIREMENTS Verification, by visual inspection, that all personnel access doors and equipment hatches between the upper and lower containment compartments are closed provides assurance that divider barrier integrity is maintained prior to the reactor being taken from MODE 5 to MODE 4. This SR is necessary because many of the doors and hatches may have been opened for maintenance during the shutdown. Verification, by visual inspection, that the personnel access door and equipment hatch seals, sealing surfaces, and alignments are acceptable provides assurance that divider barrier integrity is maintained. This inspection cannot be made when the door or hatch is closed. Therefore, SR 3.6.17.2 is required for each door or hatch that has been opened, prior to the final closure. Some doors and hatches may not be opened for long periods of time.
rhose that use resilient materials in the seals must be opened and inspected at least once every 10 years to provide assurance that the seal material has not aged to the point of degraded performance.
The Frequency of 10 years is based on the known resiliency of the materials used for seals, the fact that the openings have not been opened (to cause wear), and operating experience that confirms that the seals inspected at this Frequency have been found to be " acceptable.
@z&!&. WOG STS B 3.6.17-4 Rev. 3.0, 03/31/04 Divider Barrier Integrity (Ice Condenser)
B 3.6.17 BASES ACTIONS (continued)
C.1 and C.2 If divider barrier integrity cannot be restored to OPERABLE status within the required Completion Time, the plant must be brought to a MODE in which the LCO does not apply.To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 5 within 36 hours.The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.SURVEILLANCE REQUIREMENTS SR 3.6.17.1 Verification, by visual inspection, that all personnel access doors and equipment hatches between the upper and lower containment compartmentsareclosed provides assurance that divider barrier integrity is maintained prior to the reactor being taken from MODE 5 to MODE 4.This SR is necessary because many of the doors and hatches may have been opened for maintenance during the shutdown.SR 3.6.17.2 Verification, by visual inspection, that the personnel access door and equipment hatch seals, sealing surfaces, and alignments are acceptable provides assurance that divider barrier integrity is maintained.
This inspection cannot be made when the door or hatch is closed.Therefore, SR 3.6.17.2 is required for each door or hatch that has been opened, prior to the final closure.Some doors and hatches may not be opened for long periods of time.l.fhose that use resilient materials in the seals must be opened and inspected atleastonce every 10 years to provide assurance that the seal material has not aged to the point of degraded performance.
The Frequency of 10 years is based on the known resiliency of the materials used for seals, the fact that the openings have not been opened (to cause wear), and operating experience that confirms that the seals inspected at this Frequency have been found to be r"',t"'"\ac.__..-=-.,---WOGSTS B 3.6.17-4 Rev.3.0, 03/31/04 BASES Divider Barrier Integrity (Ice Condenser)
B 3.6.17 SURVEILLANCE REQUIREMENTS (continued)
Verification, by visual inspection, after each opening of a personnel access door or equipment hatch that it has been closed makes the operator aware of the importance of closing it and thereby provides additional assurance that divider barrier integrity is maintained while in applicable MODES. Conducting periodic physical property tests on divider barrier seal test coupons provides assurance that the seal material has not degraded in the containment environment, including the effects of irradiation with the reactor at power. The required tests include a tensile strength test [and a test for elongation].rfhe Frequency of
[I81 months was developed considering such factors as the known resiliency of the seal material used, the inaccessibility of the seals and absence of traffic in their vicinity, and the unit conditions needed to perform the SR. Operating experience has shown that these components usually pass the Surveillance when performed at the [I 81 month Frequency. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.
e-u Visual inspection of the seal around the perimeter provides assurance that the seal is properly secured in place. che Frequency of
[I81 months was developed considering such factors as the inaccessibility of the seals and absence of traffic in their vicinity, the strength of the bolts and mechanisms used to secure the seal, and the unit conditions needed to perform the SR. Operating experience has shown that these components usually pass the Surveillance when performed at the
[18] month Frequency. Therefore, the Frequency was concluded to be accepta from a reliability standpoint.
.+- -.- . - ---+--.- " " , + _ __* _ _ REFERENCES
: 1. FSAR, Section r6.21. WOG STS Rev. 3.0, 03/31/04 Divider Barrier Integrity (Ice Condenser)
B 3.6.17 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.6.17.3 Verification, by visual inspection, after each opening of a personnel access door or equipment hatch that it has been closed makes the operator aware of the importance of closing it and thereby provides additional assurance that divider barrier integrity is maintained while in applicable MODES.SR 3.6.17.4 Conducting periodic physical property tests on divider barrier seal test coupons provides assurance that the seal material has not degraded in the containment environment, including the effects of irradiation with the reactor at power.The required tests include a tensile strength test[anda test for elongation].[fhe Frequency of[18]months was developed consideringsuchfactors as the known resiliency of the seal material used, the inaccessibility of the seals and absence of traffic in their vicinity, and the unit conditions needed to perform the SR.Operating experience has shown that these components usually pass the Surveillance when performed at the[18]month Frequency.
Therefore, the
.--.-r:D concluded to be acceptable from a reliability standpoint.J:t\Se..r'---J:
SR 3.6.17.5 Visual inspection of the seal around the perimeter provides assurance that the seal is properly secured in place.Q]ie Frequency of[18]months wasdevelopedconsidering such factors as the inaccessibility of the seals and absence of traffic in their vicinity, the strength of the bolts and mechanisms used to secure the seal, and the unit conditions needed to perform the SR.Operating experience has shown that these components usually pass the Surveillance when performed at the[18]month
..
Se:ID REFERENCES WOG STS 1.FSAR, Section[6.2].B 3.6.17-5 Rev.3.0, 03/31/04 Containment Recirculation Drains (Ice Condenser)
B 3.6.18 BASES SURVEILLANCE SR 3.6.18.1 REQUIREMENTS Verifying the OPERABILITY of the refueling canal drains ensures that they will be able to perform their functions in the event of a DBA. This Surveillance confirms that the refueling canal drain plugs have been removed and that the drains are clear of any obstructions that could impair their functioning.
In addition to debris near the drains, attention must be given to any debris that is located where it could be moved to the drains in the event that the Containment Spray System is in operation and water is flowing to the drains.
SR 3.6.18.1 must be performed before entering MODE 4 from MODE 5 after every filling of the canal to ensure that the plugs have been removed and that no debris that could impair the drains was deposited during the time the canal was filled.Ehe 92 day Frequency was developed considering such factors as the inaccessibility of the drains, the absence of traffic in the vicinity of the drains, and the redundancy of the drains.
f--a .,, Verifying the OPERABILITY of the ice condenser floor drains ensures that they will be able to perform their functions in the event of a DBA. Inspecting the drain valve disk ensures that the valve is performing its function of sealing the drain line from warm air leakage into the ice condenser during normal operation, yet will open if melted ice fills the line following a DBA. Verifying that the drain lines are not obstructed ensures their readiness to drain water from the ice condenser.
ghe [I81 month Frequency was developed considering such factors as the inaccessibility of the drains during power operation; the design of the ice condenser, which precludes melting and refreezing of the ice; and operating experience that has confirmed that the drains are found to be acceptable when the Surveillance is performed at an [I&] month Frequency. Because of high radiation in the vicinity of the drains during power REFERENCES
: 1. FSAR, Section [6.2]. WOE STS Rev. 3.0, 03/31/04 Containment Recirculation Drains (Ice Condenser)
B 3.6.18 BASES SURVEILLANCE REQUIREMENTS SR 3.6.18.1 Verifying the OPERABILITY of the refueling canal drains ensures that they will be able to perform their functions in the event of a DBA This Surveillance confirms that the refueling canal drain plugs have been removed and that the drains are clear of any obstructions that could impair their functioning.
In addition to debris near the drains, attention must be given to any debris that is located where it could be moved to the drains in the event that the Containment Spray System is in operation and water is flowing to the drains.SR 3.6.18.1 must be performed before entering MODE 4 from MODE 5 after every filling of the canal to ensure that the plugs have been removed and that no debris that could impair the drains was deposited during the time the canal was filled.me 92 day Frequency was developed considering such factors as the inaccessibility of the drains, the absence of traffic in the vicinity of the drains.and the redundancy of the drains.
=r:
-----SR 3.6.18.2 FSAR, Section[6.2].1.Verifying the OPERABILITY of the ice condenser floor drains ensures that they will be able to perform their functions in the event of a DBA.Inspecting the drain valve disk ensures that the valve is performing its function of sealing the drain line from warm air leakage into the ice condenser during normal operation, yet will open if melted ice fills the line following a DBA.Verifying that the drain lines are not obstructed ensures their readiness to drain water from the ice condenser.l1he
[18]month Frequency was developed considering such factors as the inaccessibility of the drains during power operation; the design of the ice condenser, which precludes melting and refreezing of the ice;and operating experience that has confirmed that the drains are found to be acceptable when the Surveillance is performed at an[18]month Frequency.
Because of high radiation in the vicinity of the drains during power operation, this Surveillance is normally done during a shutdown.REFERENCES WOGSTS B 3.6.18A Rev.3.0, 03/31/04 MSlVs B 3.7.2 BASES ACTIONS (continued)
D.1 and D.2 If the MSlVs cannot be restored to OPERABLE status or are not closed within the associated Completion Time, the unit must be placed in a MODE in which the LC0 does not apply. To achieve this status, the unit must be placed at least in MODE 3 within 6 hours, and in MODE 4 within 12 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required unit conditions from MODE 2 conditions in an orderly manner and without challenging unit systems. SURVEILLANCE SR 3.7.2.1 REQUIREMENTS This SR verifies that MSlV closure time is S [4.6] seconds. The MSlV isolation time is assumed in the accident and containment analyses. This Surveillance is normally performed upon returning the unit to operation following a refueling outage. The MSlVs should not be tested at power, since even a part stroke exercise increases the risk of a valve closure when the unit is generating power.
As the MSlVs are not tested at power, they are exempt from the ASME Code (Ref. 5), requirements during operation in MODE I or 2. The Frequency is in accordance with the Inservice Testing Program. This test is conducted in MODE 3 with the unit at operating temperature and pressure. This SR is modified by a Note that allows entry into and operation in MODE 3 prior to performing the SR. This allows a delay of testing until MODE 3, to establish conditions consistent with those under which the acceptance criterion was generated.
This SR verifies that each MSIV can close on an actual or simulated actuation signal.
This Surveillance is normally performed upon returning the plant to operation following a refueling outage. Ehe Frequency of MSlV testing is every ['I81 months. The [18] month Frequency for testing is based on the refueling cycle. Operating experience has shown that these components usually pass the Surveillance when performed at the [I81 month Frequency.
Therefore, this Frequency is acceptable from a reliability standpoint, +-, WOG STS -- Rev. 3.1, 12/01/05 MSIVs B 3.7.2 BASES ACTIONS (continued) 0,1 and 02 If the MSIVs cannot be restored to OPERABLE status or are not closed within the associated Completion Time, the unit must be placed in a MODE in which the LCO does not apply.To achieve this status, the unit must be placed at least in MODE 3 within 6 hours, and in MODE 4 within 12 hours.The allowed Completion Times are reasonable, based on operating experience, to reach the required unit conditions from MODE 2 conditions in an orderly manner and without challenging unit systems.SURVEILLANCE SR 3.7.2.1 REQUIREMENTS This SR verifies that MSIV closure time is S[4.6]seconds.The MSIV isolation time is assumed in the accident and containment analyses.This Surveillance is normally performed upon returning the unit to operation following a refueling outage.The MSIVs should not be tested at power, since even a part stroke exercise increases the risk of a valve closure when the unit is generating power.As the MSIVs are not tested at power, they are exempt from the ASME Code (Ref.5), requirements during operation in MODE 1 or 2.The Frequency is in accordance with the Inservice Testing Program.This test is conducted in MODE 3 with the unit at operating temperature and pressure.This SR is modified by a Note that allows entry into and operation in MODE 3 prior to performing the SR.This allows a delay of testing until MODE 3, to establish conditions consistent with those under which the acceptance criterion was generated.
SR 3.7.2.2 This SR verifies that each MSIV can close on an actual or simulated actuation signal.This Surveillance is normally performed upon returning the plant to operation following a refueling outage./Ihe Frequency of MSIV testing is every[18]months.The[18]month Frequency for testing is based on the refueling cycle.Operating experience has shown that these components usually pass the Surveillance when performed at the[18]month Frequency.
Therefore, this Frequency is acceptable from a reliability standpoint.
WOGSTS B 3,7.2-5 Rev.3.1, 12/01/05 MFlVs and MFRVs [and Associated Bypass Valves]
B 3.7.3 BASES -- - -- SURVEILLANCE REQUIREMENTS (continued)
This SR verifies that each MFIV, MFRV, and [associated bypass valves]
can close on an actual or simulated actuation signal. This Surveillance is normally performed upon returning the plant to operation following a refueling outage.
&e Frequency for this SR is every 1181 months. The [I81 month Frequency for testing is based on the refueling cycle. Operating experience has shown that these components usually pass the Surveillance when performed at the [I81 month Frequency. Therefore, this Frequency is acceptable from a reliability standpoint.
f-) REFERENCES
: 1. FSAR, Section [10.4.7].
<~r,~er b!??) 2. ASME Code for Operation and Maintenance of Nuclear Power Plants. WOG STS Rev. 3.1, 12101105 MFIVs and MFRVs[and Associated Bypass ValvesJ B 3.7.3 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.7.
 
==3.2 REFERENCES==
 
This SR verifies that each MFIV, MFRV, and[associated bypass valvesJ can close on an actual or simulated actuation signal.This Surveillance is normally performed upon returning the plant to operation following a refueling outage.Ube Frequency for this SR is every[18]months.The[18J month Frequency for testing is based on the refueling cycle.Operating experience has shown that these components usually pass the Surveillance when performed at the[18]month Frequency.
Therefore, this Frequency is acceptable from a reliability standpoint.
1.FSAR, Section[10.4.7].2.ASME Code for Operation and Maintenance of Nuclear Power Plants.WOGSTS B 3.7.3-6 Rev.3.1,12/01/05 ADVs B 3.7.4 BASES SURVEILLANCE SR 3.7.4.1 REQUIREMENTS To perform a controlled cooldown of the RCS, the ADVs must be able to be opened either remotely or locally and throttled through their full range.
This SR ensures that the ADVs are tested through a full control cycle at least once per fuel cycle. Performance of inservice testing or use of an ADV during a unit cooldown may satisfy this requirement.
Gerating experience has shown that these components usually pass the Surveillance when performed at the [I81 month Frequency.
The Frequency is acceptable from a reliability standpoint.
f-. The function of the block valve is to isolate a failed open ADV. Cycling the block valve both closed and open demonstrates its capability to perform this function. Performance of inservice testing or use of the block valve during unit cooldown may satisfy this requirement.
EPerating experience has shown that these components usually pass the Surveillance when performed at the
[I81 month Frequency. The Frequency is acceptable from a reliability standpoint,] - REFERENCES I. FSAR, Section
[10.3]. WOG STS Rev. 3.0, 03/31/04 BASES SURVEILLANCE REQUIREMENTS ADVs B 3.7.4 SR 3.7.4.1 To perform a controlled cooldown of the RCS, the ADVs must be able to be opened either remotely or locally and throttled through their full range.This SR ensures that the ADVs are tested through a full control cycle atleastonce per fuel cycle.Performance of inservice testing or use of an ADV during a unit cooldown may satisfy this requirement.
@Perating experience has shown that these components usually pass the Surveillance when performed at the[18]month Frequency.
The Frequency is acceptable from a reliability standpoint.[SR 3.7.4.2 The function of the block valve is to isolate a failed open ADV.Cycling the block valve both closed and open demonstrates its capability to perform this function.Performance of inservice testing or use of the block valve during unit cooldown may satisfy this requirement.
@perating experience has shown that these components usually pass the Surveillance when performed at the[18]month Frequency.
The Frequency is acceptable from a reliability standpoint.
]REFERENCES 1.FSAR, Section[10.3].Ih5er-tz WOGSTS B 3.7.4-4 Rev.3.0, 03/31/04 AFW System B 3.7.5 BASES SURVEILLANCE REQUIREMENTS (continued)
[ The SR is modified by a Note that states one or more AFW trains may be considered OPERABLE during alignment and operation for steam generator level control, if it is capable of being manually (i.e., remotely or locally, as appropriate) realigned to the AFW mode of operation, provided it is not otherwise inoperable.
This exception allows the system to be out of its normal standby alignment and temporarily incapable of automatic initiation without declaring the train(s) inoperable. Since AFW may be used during startup, shutdown, hot standby operations, and hot shutdown operations for steam generator level control, and these manual operations are an accepted function of the AFW System, OPERABILITY (i.e., the intended safety function) continues to be maintained.
] Ge 31 day Frequency is based on engineering judgment, is consistent with the procedural controls governing valve operation, and ensures correct valve positions.+~~-
,-". -..,.*-,-- Verifying that each AFW pump's developed head at the flow test point is greater than or equal to the required developed head ensures that AFW pump performance has not degraded during the cycle. Flow and differential head are normal tests of centrifugal pump performance required by the ASME Code (Ref 2). Because it is undesirable to introduce cold AFW into the steam generators while they are operating, this testing is performed on recirculation flow. This test confirms one point on the pump design curve and is indicative of overall performance.
Such inservice tests confirm component OPERABILITY, trend performance, and detect incipient failures by indicating abnormal performance. Performance of inservice testing discussed in the ASME Code (Ref. 2) (only required at 3 month intervals) satisfies this requirement.
[ This SR is modified by a Note indicating that the SR should be deferred until suitable test conditions are established.
This deferral is required because there is insufficient steam pressure to perform the test.
] WOG STS - Rev. 3.1, 12/01/05 AFW System B 3.7.5 BASES SURVEILLANCE REQUIREMENTS (continued)
[The SR is modified by a Note that states one or more AFW trains may be considered OPERABLE during alignment and operation for steam generator level control, if it is capable of being manually (i.e., remotely or locally, as appropriate) realigned to the AFW mode of operation, provided it is not otherwise inoperable.
This exception allows the system to be out of its normal standby alignment and temporarily incapable of automatic initiation without declaring the train(s)inoperable.
Since AFW may be used during startup, shutdown, hot standby operations, and hot shutdown operations for steam generator level control, and these manual operations are an accepted function of the AFW System, OPERABILITY (i.e., the intended safety function)continues to be maintained.
] 31 day Frequency is based on engineering judgment, is consistent with the procedural controls governing valve operation, and ensures correct valve
..-Ir\5ert__......',_WlII't'" SR 3.7.5.2 Verifying that each AFW pump's developed head at the flow test point is greater than or equal to the required developed head ensures that AFW pump performance has not degraded during the cycle.Flow and differential head are normal tests of centrifugal pump performance required by the ASME Code (Ref 2).Because it is undesirable to introduce cold AFW into the steam generators while they are operating, this testing is performed on recirculation flow.This test confirms one point on the pump design curve and is indicative of overall performance.
Such inservice tests confirm component OPERABILITY, trend performance, and detect incipient failures by indicating abnormal performance.
Performance of inservice testing discussed in the ASME Code (Ref.2)(only required at 3 month intervals) satisfies this requirement.
[This SR is modified by a Note indicating that the SR should be deferred until suitable test conditions are established.
This deferral is required because there is insufficient steam pressure to perform the test.]WOGSTS B 3.7.5-7 Rev.3.1, 12/01/05 AFW System B 3.7.5 BASES SURVEILLANCE REQUIREMENTS (continued)
This SR verifies that AFW can be delivered to the appropriate steam generator in the event of any accident or transient that generates an ESFAS, by demonstrating that each automatic valve in the flow path actuates to its correct position on an actual or simulated actuation signal. This Surveillance is not required for valves that are locked, sealed, or otherwise secured in the required position under administrative controls.
The [I81 month Frequency is based on the need to perform this urveillance under the conditions that apply during a unit outage and the C potential for an unplanned transient if the Surveillance were performed with the reactor at power. The [I81 month Frequency is acceptable based on operating experience and the design reliability of the equipment.
[ The SR is modified by a Note that states one or more AFW trains may be considered OPERABLE during alignment and operation for steam generator level control, if it is capable of being manually (i.e., remotely or locally, as appropriate) realigned to the AFW mode of operation, provided it is not otherwise inoperable. This exception allows the system to be out of its normal standby alignment and temporarily incapable of automatic initiation without declaring the train(s) inoperable. Since AFW may be used during startup, shutdown, hot standby operations, and hot shutdown operations for steam generator level control, and these manual operations are an accepted function of the AFW System, OPERABILITY (i.e., the intended safety function) continues to be maintained.
] This SR is modified by a Note that states the SR is not required in MODE 4. In MODE 4, the required AFW train is already aligned and operating.
This SR verifies that the AFW pumps will start in the event of any accident or transient that generates an ESFAS by demonstrating that each AFW pump starts automatically on an actual or simulated actuation signal in MODES 1, 2, and 3. In MODE 4, the required pump is already operating and the autostart function is not required.
@e [I81 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a unit outage and the potential for an unplanned transient if the Surveillance were serformed with the reactor at WOG STS B 3.7.5-8 Rev. 3.1, 12/01/05 AFW System B 3.7.5 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.7.5.3 This SR verifies that AFW can be delivered to the appropriate steam generator in the event of any accident or transient that generates an ESFAS, by demonstrating that each automatic valve in the flow path actuates to its correct position on an actual or simulated actuation signal.This Surveillance is not required for valves that are locked, sealed, or otherwise secured in therequiredposition under administrative controls.me[18]month Frequency is based on the need to perform this under the conditions that apply during a unit outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power.The[18]month Frequency is acceptable based on operating experience and the design reliability of the equipment.
[The SR is modified by a Note that states one or more AFW trains may be considered OPERABLE during alignment and operation for steam generator level control, if it is capable of being manually (Le., remotely or locally, as appropriate) realigned to the AFW mode of operation, provided it is not otherwise inoperable.
This exception allows the system to be out of its normal standby alignment and temporarily incapable of automatic initiation without declaring the train(s)inoperable.
Since AFW may be used during startup, shutdown, hot standby operations, and hot shutdown operations for steam generator level control, and these manual operations are an accepted function of the AFW System, OPERABILITY (Le., the intended safety function)continues to be maintained.
]This SR is modified by a Note that states the SR is not required in MODE 4.In MODE 4, the required AFW train is already aligned and operating.
SR 3.7.5.4 This SR verifies that the AFW pumps will start in the event of any accident or transient that generates an ESFAS by demonstrating that each AFW pump starts automatically on an actual or simulated actuation signal in MODES 1, 2, and 3.In MODE 4, the required pump is already operating and the autostart function is not required.[be[18]month Frequency is based on the need to perform this Surveillance under the conditions that apply during a unit outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at
.
WOGSTS B 3.7.5-8 Rev.3.1,12/01/05 CST B 3.7.6 BASES ACTIONS A.l and A.2 If the CST is not OPERABLE, the OPERABILITY of the backup supply should be verified by administrative means within 4 hours and once every 12 hours thereafter. OPERABILITY of the backup feedwater supply must include verification that the flow paths from the backup water supply to the AFW pumps are OPERABLE, and that the backup supply has the required volume of water available.
The CST must be restored to OPERABLE status within 7 days, because the backup supply may be performing this function in addition to its normal functions. The 4 hour Completion Time is reasonable, based on operating experience, to verify the OPERABILITY of the backup water supply. Additionally, verifying the backup water supply every 12 hours is adequate to ensure the backup water supply continues to be available. The 7 day Completion Time is reasonable, based on an OPERABLE backup water supply being available, and the low probability of an event occurring during this time period requiring the CST. B.l and B.2 If the CST cannot be restored to OPERABLE status within the associated Completion Time, the unit must be placed in a MODE in which the LC0 does not apply. To achieve this status, the unit must be placed in at least MODE 3 within 6 hours, and in MODE 4, without reliance on the steam generator for heat removal, within
[24] hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required unit conditions from full power conditions in an orderly manner and without challenging unit systems.
SURVEILLANCE SR 3.7.6.1 REQUIREMENTS This SR verifies that the CST contains the required volume of cooling water. (The require CST volume may be single value or a function of RCS conditions.)
f The 12 hour Frequency is based on operating experience and the need for operator awareness of unit evolutions that may affect the CST inventory between checks. Also, the 12 hour Frequency is considered adequate in view of other indications in the control room, including alarms, to alert the operator to abnormal deviations in the CST level.
r "--. REFERENCES
: 1. FSAR, Section [9.2.6]. (1n~ert2)
: 2. FSAR, Chapter [6]. 3. FSAR, Chapter 1151. WOG STS -- B 3.7.6-3 Rev. 3.0.
03/31/04 CST B 3.7.6 BASES ACTIONS A.1 and A.2 If the CST is not OPERABLE, the OPERABILITY of the backup supply should be verified by administrative means within 4 hours and once every 12 hours thereafter.
OPERABILITY of the backup feedwater supply must include verification that the flow paths from the backup water supply to the AFW pumps are OPERABLE, and that the backup supply has the required volume of water available.
The CST must be restored to OPERABLE status within 7 days, because the backup supply may be performing this function in addition to its normal functions.
The 4 hour Completion Time is reasonable, based on operating experience, to verify the OPERABILITY of the backup water supply.Additionally, verifying the backup water supply every 12 hours is adequate to ensure the backup water supply continues to be available.
The 7 day Completion Time is reasonable, based on an OPERABLE backup water supply being available, and the low probability of an event occurring during this time period requiring the CST.B.1 and B.2 If the CST cannot be restored to OPERABLE status within the associated Completion Time, the unit must be placed in a MODE in which the LCO does not apply.To achieve this status, the unit must be placed in at least MODE 3 within 6 hours, and in MODE 4, without reliance on the steam generator for heat removal, within[24]hours.The allowed Completion Times are reasonable, based on operating experience, to reach the required unit conditions from fuff power conditions in an orderly manner and without challenging unit systems.SURVEILLANCE REQUIREMENTS SR 3.7.6.1 I..n3er 2 1.FSAR, Section[9.2.6].This SR verifies that the CST contains the required volume of cooling water.(The requi!&sect;.d CST volume may be single value or a function of RCS conditions.)
ille 12 hour Frequency is based on operating experience and the need for operator awareness of unitevolutionsthat may affect the CST inventory between checks.Also, the 12 hour Frequency is considered adequate in view of other indications in the control room, including alarms, to alert the operator to abnormal deviations in the CST level.REFERENCES 2.FSAR, Chapter[6}.3.FSAR, Chapter[15}.WOGSTS B 3.7.6-3 Rev.3.0, 03/31/04 CCW System B 3.7.7 BASES SURVEILLANCE REQUIREMENTS (continued) sealing, or securing. This SR also does not apply to valves that cannot be inadvertently misaligned, such as check valves. This Surveillance does not require any testing or valve manipulation; rather, it involves verification that those valves capable of being mispositioned are in the ,correct position.
Ge 31 day Frequency is based on engineering judgment, is consistent with the procedural controls governing valve operation, and ensures correct valve positions.
& @sew This SR verifies proper automatic operation of the CCW valves on an actual or simulated actuation signal.
The CCW System is a normally operating system that cannot be fully actuated as part of routine testing during normal operation. This Surveillance is not required for valves that are locked, sealed, or otherwise secured in the required position under administrative controls.
Ehe [18] month Frequency is based on the need to perform this Surveillance under the conditions that apply during a unit outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power. Operating experience has shown that these components usually pass the Surveillance when performed at the
[I81 month Frequency.
Therefore, the Frequency is acceptable from a reliability standpoint.
t-t, ,-.---------w-, - '~ri~evt VJ kt=:---- This SR verifies proper automatic operation of the CCW pumps on an actual or simulated actuation signal. The CCW System is a normally operating system that cannot be fully actuated as part of routine testing during normal operation.
Ehe [I81 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a unit outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power. Operating experience has shown that these components usually pass the Surveillance when performed at the [18] month Frequency.
Therefore, the Frequency is acceptable from a reliability standpoint.
&+, REFERENCES
: 1. FSAR, Section [9.2.2]. 2. FSAR, Section [6.2]. WOG STS Rev. 3.0, 03/31/04 CCW System B 3.7.7 BASES SURVEILLANCE REQUIREMENTS (continued) sealing, or securing.This SR also does not apply to valves that cannot be inadvertently misaligned, such as check valves.This Surveillance does not require any testing or valve manipulation; rather, it involves verification that those valves capable of being mispositioned are in the ,correct position.me 31 day Frequency is based on engineering judgment, is consistent with the procedural controls governing valve operation, and ensures correct valve positions.
Se;-J2J SR 3.7.7.2 This SR verifies proper automatic operation of the CCW valves on an actual or simulated actuation signal.The CCW System is a normally operating system that cannot be fully actuated as part of routine testing during normal operation.
This Surveillance is not required for valves that are locked, sealed, or otherwise secured in the required position under administrative controls.rIbe[18]month Frequency is based on the need to perform this Surveillance under the conditions that apply during a unit outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power.Operating experience has shown that these components usually pass the Surveillance when performed at the[18]month Frequency.
Therefore, the Frequency is acceptable from a reliability standpoint.
;f:,...-------t.
SR 3.7.
 
==7.3 REFERENCES==
 
This SR verifies proper automatic operation of the CCW pumps on an actual or simulated actuation signal.The CCW System is a normally operating system that cannot be fully actuated as part of routine testing during normal operation.
[he[18]month Frequency is based on the need to perform this Surveillance under the conditions that apply during a unit outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power.Operating experience has shown that these components usually pass the Surveillance when performed at the[18]month Frequency.
Therefore, the Frequency is acceptable from a reliability standpoint.
1.FSAR, Section[9.2.2].2.FSAR, Section[6.2J.WOGSTS B 3.7.7-4 Rev.3.0, 03/31/04 SWS B 3.7.8 BASES ACTIONS (continued)
LC0 3.0.6 and ensures the proper actions are taken for these components. The 72 hour Completion Time is based on the redundant capabilities afforded by the OPERABLE train, and the low probability of a DBA occurring during this time period.
B.l and B.2 If the SWS train cannot be restored to OPERABLE status within the associated Completion Time, the unit must be placed in a MODE in which the LC0 does not apply. To achieve this status, the unit must be placed in at least MODE 3 within 6 hours and in MODE 5 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required unit conditions from full power conditions in an orderly manner and without challenging unit systems. SURVEILLANCE SR 3.7.8.1 REQUIREMENTS This SR is modified by a Note indicating that the isolation of the SWS components or systems may render those components inoperable, but does not affect the OPERABILITY of the SWS. Verifying the correct alignment for manual, power operated, and automatic valves in the SWS flow path provides assurance that the proper flow paths exist for SWS operation.
This SR does not apply to valves that are locked, sealed, or otherwise secured in position, since they are verified to be in the correct position prior to being locked, sealed, or secured. This SR does not require any testing or valve manipulation; rather, it involves verification that those valves capable of being mispositioned are in the correct position. This SR does not apply to valves that cannot be inadvertently misaligned, such as check valves. Ee 31 day Frequency is based on engineering judgment, is consistent with the procedural controls governing valve operation, and ensures correct valve positions.
+ . . ,, .s7-. --. - -. 1- -- ~n5erk-J WOG STS B 3.7.8-3 Rev. 3.0, 03/31/04 SWS B 3.7.8 BASES ACTIONS (continued)
LCO 3.0.6 and ensures the proper actions are taken for these components.
The 72 hour Completion Time is based on the redundant capabilities afforded by the OPERABLE train, and the low probability of a DBA occurring during this time period.B.1 and B.2 If the SWS train cannot be restored to OPERABLE status within the associated Completion Time, the unit must be placed in a MODE in which the LCO does not apply.To achieve this status, the unit must be placed in at least MODE 3 within 6 hours and in MODE 5 within 36 hours.The allowed Completion Times are reasonable, based on operating experience, to reach the required unit conditions from full power conditions in an orderly manner and without challenging unit systems.SURVEILLANCE REQUIREMENTS SR 3.7.8.1 This SR is modified by a Note indicating that the isolation of the SWS components or systems may render those components inoperable, but does not affect the OPERABILITY of the SWS.Verifying the correct alignment for manual, power operated, and automatic valves in the SWS flow path provides assurance that the proper flow paths exist for SWS operation.
This SR does not apply to valves that are locked, sealed, or otherwise secured in position, since they are verified to be in the correct position prior to being locked, sealed, or secured.This SR does not require any testing or valve manipulation; rather, it involves verification thatthosevalves capable of being mispositioned are in the correct position.This SR does not apply to valves that cannot be inadvertently misaligned, such as check valves.[!be 31 day Frequency is based on engineering judgment, is consistent with the procedural controls governing valve operation, and ensures correct valve positions.
WOGSTS B 3.7.8-3 Rev.3.0, 03/31/04 SWS B 3.7.8 BASES SURVEILLANCE REQUIREMENTS (continued)
This SR verifies proper automatic operation of the SWS valves on an actual or simulated actuation signal.
The SWS is a normally operating system that cannot be fully actuated as part of normal testing. This Surveillance is not required for valves that are locked, sealed, or otherwise secured in the required position under administrative controls.
Ehe [18] month Frequency is based on the need to perform this Surveillance under the conditions that apply during a unit outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power. Operating experience has shown that these components usually pass the Surveillance when performed at the 1181 month ~reauencv. Therefore, the
~reauencv is acceptable from a ;eliebility standpoint.
~Z.e~t~ This SR verifies proper automatic operation of the SWS pumps on an actual or simulated actuation signal.
The SWS is a normally operating system that cannot be fully actuated as part of normal testing during normal operation.
Ehe 1181 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a unit outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power. Operating experience has shown that these components usually pass the Surveillance when performed at the [I81 month ~requency.
Therefore, the Frequency is acceptable from a reliability standpoint.
d--, - REFERENCES
: 1. FSAR, Section
[9.2.1]. (~r\s& 2) 2. FSAR, Section [6.2]. 3. FSAR, Section [5.4.7]. WOG STS Rev. 3.0, 03/31/04 SWS B 3.7.8 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.7.8.2 This SR verifies proper automatic operation of the SWS valves on an actual or simulated actuation signal.The SWS is a normally operating system that cannot be fully actuated as part of normal testing.This Surveillance is not required for valves that are locked, sealed, or otherwise secured in the required position under administrative controls.JTI1e[18]month Frequency is based on the need to perform this Surveillance under the conditions that apply during a unit outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power.Operating experience has shown that these components usually pass the Surveillance when performed at the[18]month Frequency.
Therefore, the Frequency is acceptable from a reliability standpoint.
SR 3.7.
 
==8.3 REFERENCES==
 
This SR verifies proper automatic operation of the SWS pumps on an actual or simulated actuation signal.The SWS is a normally operating system that cannot be fully actuated as part of normal testing during normal operation.
[he[18]month Frequency is based on the need to perform this Surveillance under the conditions that apply during a unit outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power.Operating experience has shown that these components usually pass the Surveillance when performed at the[18]month Frequency.
Therefore, the Frequency is acceptable from a reliability standpoint.2.FSAR, Section[6.2].3.FSAR, Section[5.4.7].WOGSTS B 3.7.8-4 Rev.3.0, 03/31/04 UHS B 3.7.9 BASES SURVEILLANCE
[ SR 3.7.9.1 REQUIREMENTS This SR verifies that adequate long term (30 day) cooling can be maintained. The specified level also ensures that sufficient NPSH is available to operate the SWS pumps.
rhe [24] hour Frequency is based on operating experience related to trending of the parameter variations during the applicable MODES. This SR verifies that the UHS water level is 5: [562] ft [mean sea
[SR 3.7.9.2 This SR verifies that the SWS is available to cool the CCW System to at least its maximum design temperature with the maximum accident or rmal design heat loads for 30 days following a Design Basis Accident.
The 24 hour Frequency is based on operating experience related to C rending of the parameter variations during the applicable MODES. This SR verifies that the average water temperature of the UHS is 2 [so'FP~) [SR 3.7.9.3 Operating each cooling tower fan for 2[15] minutes ensures that all fans are OPERABLE and that all associated controls are functioning properly.
It also ensures that fan or motor failure, or excessive vibration, can be detected for corrective action.
Ee 31 day Frequency is based on operating experience, the known reliability of the fan units, the redundancy available, and the low probability of significant degradation of the UHS cooling tower fans occurring between surveillances.
d This SR verifies that each cooling tower fan starts and operates on an actual or simulated actuation signal. Ehe [I81 month Frequency is consistent with the typical refueling cycle. Operating experience has shown that these components usually pass the Surveillance when performed at the
[I81 month Frequency. Therefore, the Frequency is acceptable from a reliability standpoint.
] REFERENCES 1.
FSAR, Section [9.2.5]. c(m5dX 2. Regulatory Guide 1 Z. WOG STS Rev. 3.0, 03/31/04 [SR 3.7.9.3 BASES SURVEILLANCE REQUIREMENTS UHS B 3.7.9[SR 3.7.9.1 This SR verifies that adequate long term (30 day)cooling can be maintained.
The specified level also ensures that sufficient NPSH is available to operate the SWS pumps.[fhe[24]hour Frequency is based on operating experience related to trending of the parameter variations during the applicable MODES.This SR verifies that the UHS water level is;;:[562]ft[mean sea level].],""----'""1:':''''''''\
t...---(X!\
5 e y E:Y-d*[SR 3.7.9.2 This SR verifies that the SWS is available to cool the CCW System to at least its maximum design temperature with the maximum accident or design heat loads for 30 days following a Design Basis Accident.The 24 hour Frequency is based on operating experience related to rending of the parameter variations during the applicable MODES,SR verifies that the average water temperature of the UHS is::;;[90&deg;F].J J"--'-',rtJ)
Operating each cooling tower fan for;;:[15]minutes ensures that all fans are OPERABLE and that all associated controls are functioning properly.It also ensures that fan or motor failure.or excessive vibration.
can be detected for corrective action.@e 31 day Frequency is based on operating experience, the known reliability of the fan units.the redundancy available.
and the low probability of significant degradation of the UHS cooling tower fans occurring between_
[SR 3.7.9.4 This SR verifies that each cooling tower fan starts and operates on an actual or simulated actuation signal.Uhe[18]month Frequency is consistent with the typical refueling cycle, Operating experience has shown that these components usually pass the Surveillance when performed at the[18]month Frequency.
Therefore, the Frequency is acceptable from a reliability standpoint.
J REFERENCES WOGSTS 1.FSAR, Section[9.2.5].2.Regulatory Guide 1.27.B 3.7.9-4 I.nsertA..
Rev.3.0, 03/31/04 CREFS B 3.7.10 BASES ACTIONS (continued) [In MODE 5 or 6, or] during movement of [recently] irradiated fuel assemblies, with two CREFS trains inoperable, action must be taken immediately to suspend activities that could result in a release of radioactivity that might enter the control room. This places the unit in a condition that minimizes accident risk. This does not preclude the movement of fuel to a safe position.
If both CREFS trains are inoperable in MODE 1,2, 3, or 4 for reasons other than an inoperable control room boundary (i.e., Condition B), the CREFS may not be capable of performing the intended function and the unit is in a condition outside the accident analyses. Therefore, LC0 3.0.3 must be entered immediately.
SURVEILLANCE SR 3.7.10.1 REQUIREMENTS Standby systems should be checked periodically to ensure that they function properly. As the environment and normal operating conditions on this system are not too severe, testing each train once every month provides an adequate check of this system. Monthly heater operations dry out any moisture accumulated in the charcoal from humidity in the ambient air. [Systems with heaters must be operated for 210 continuous hours with the heaters energized. Systems without heaters need only be operated for 215 minutes to demonstrate the function of the system.]
Ehe 31 day Frequency is based on the reliability of the equipment and the two train redundancy availability.
+, L "-- SR 3.7.10.2 This SR verifies that the required CREFS testing is performed in accordance with the [Ventilation Filter Testing Program (VFTP)]. The [VFTP] includes testing the performance of the HEPA filter, charcoal adsorber efficiency, minimum flow rate, and the physical properties of the activated charcoal. Specific test Frequencies and additional information are discussed in detail in the [VFTP].
WOG STS Rev. 3.0, 03/31/04 CREFS B 3.7.10 BASES ACTIONS (continued)
[In MODE 5 or 6, or}during movement of[recently}
irradiated fuel assemblies, with two CREFS trains inoperable, action must be taken immediately to suspend activities that could result in a release of radioactivity that might enter the control room.This places the unit in a condition that minimizes accident risk.This does not preclude the movement of fuel to a safe position.If both CREFS trains are inoperable in MODE 1, 2, 3, or 4 for reasons other than an inoperable control room boundary (i.e., Condition B), the CREFS may not be capable of performing the intended function and the unit is in a condition outside the accident analyses.Therefore, LCO 3.0.3 must be entered immediately.
SURVEILLANCE REQUIREMENTS SR 3.7.10.1 Standby systems should be checked periodically to ensure that they function properly.As the environment and normal operating conditions on this system are not too severe, testing each train once every month provides an adequate check of this system.Monthly heater operations dry out any moisture accumulated in the charcoal from humidity in the ambient air.[Systems with heaters must be operated for;:;:10 continuous hours with the heaters energized.
Systems without heaters need only-be operated for;::15 minutes to demonstrate the function of the system.)[he 31 day Frequency is based on the reliability of the equipment and the two train redundancy availability.
SR 3.7.10.2 This SR verifies that the required CREFS testing is performed in accordance with the[Ventilation Filter Testing Program (VFTP)J.The[VFTP]includes testing the performance of the HEPA filter, charcoal adsorber efficiency, minimum flow rate, and the physical properties of the activated charcoal.Specific test Frequencies and additional information are discussed in detail in the[VFTP].WOGSTS B 3.7.10-6 Rev.3.0, 03/31/04 CREFS B 3.7.10 BASES SURVEILLANCE REQUIREMENTS (continued)
This SR verifies that each CREFS train starts and operates on an actual or simulated actuation signal.
Fhe Frequency of
[I81 months is specified in Regulatory Guide 1.52 (~efx).(-
%,,+,* 2 - ,t 2) rw*.>- This SR verifies the integrity of the control room enclosure, and the assumed inleakage rates of the potentially contaminated air. The control room positive pressure, with respect to potentially contaminated adjacent areas, is periodically tested to verify proper functioning of the CREFS. During the emergency mode of operation, the CREFS is designed to pressurize the control room 2[0.125] inches water gauge positive pressure with respect to adjacent areas in order to prevent unfiltered inleakage. The CREFS is designed to maintain thi positive pressure with one train at a makeup flow rate of [3000] cfm. the Frequency of [I81 months on a STAGGERED TEST BASIS is consistent with the guidance provided in NUREG-0800 (Ref. 4). 6, REFERENCES
: 1. FSAR, Section [6.4]. 2. FSAR, Chapter [15]. 3. Regulatory Guide 1.52, Rev.
[2]. 4. NUREG-0800, Section 6.4, Rev. 2, July 1981. WOG STS Rev. 3.0, 03/31/04 CREFS B 3.7.10 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.7.10.3 This SR verifies that each CREFS train starts and operates on an actual or simulated actuation signal.[he Frequency of[18]months is specified in Regulatory Guide 1.52 (Ref.
'*.".r-Y-'I')\__A.i SR 3.7.10.4 This SR verifies the integrity of the control room enclosure, and the assumed inleakage rates of the potentially contaminated air.The control room positive pressure, with respect to potentially contaminated adjacent areas, is periodically tested to verify proper functioning of the CREFS.During the emergency mode of operation, the CREFS is designed to pressurize the control room inches water gauge positive pressure with respect to adjacent areas in order to prevent unfiltered inleakage.
The CREFS is designed to maintainpositive pressure with one train atamakeup flow rate of[3000]cfm.\.The Frequency of[18]months on a STAGGERED TEST BASIS is consistent with the guidance provided in NUREG-0800 (Ref.4).REFERENCES 1.FSAR, Section 2-2.FSAR, Chapter[15].3.Regulatory Guide 1.52, Rev.[2].4.NUREG-0800, Section 6.4, Rev.2, July 1981.WOGSTS B 3.7.10-7 Rev.3.0, 03/31/04 CREATCS B 3.7.11 BASES ACTIONS (continued)
C.1 and C.2 [In MODE 5 or 6, or] during movement of [recently] irradiated fuel, if the inoperable CREATCS train cannot be restored to OPERABLE status within the required Completion Time, the OPERABLE CREATCS train must be placed in operation immediately.
This action ensures that the remaining train is OPERABLE, that no failures preventing automatic actuation will occur, and that active failures will be readily detected. An alternative to Required Action C.1 is to immediately suspend activities that present a potential for releasing radioactivity that might require isolation of the control room. This places the unit in a condition that minimizes accident risk. This does not preclude the movement of fuel to a safe position.
[In MODE 5 or 6, or] during movement of [recently] irradiated fuel assemblies, with two CREATCS trains inoperable, action must be taken immediately to suspend activities that could result in a release of radioactivity that might require isolation of the control room. This places the unit in a condition that minimizes risk. This does not preclude the movement of fuel to a safe position. If both CREATCS trains are inoperable in MODE 1, 2, 3, or 4, the control room CREATCS may not be capable of performing its intended function.
Therefore, LC0 3.0.3 must be entered immediately.
SURVEILLANCE SR 3.7.1 1 .I REQUIREMENTS This SR verifies that the heat removal capability of the system is sufficient to remove the heat load assumed in the [safety analyses]
in the control room. This SR consists of a combination of testing and calculations.~he
[I 81 month Frequency is appropriate since significant degradation of the CREATCS is slow and is not expected over this time period.
REFERENCES
: 1. FSAR, Section 16.41. WOG STS Rev. 3.0, 03131104 CREATCS B3.7.11 BASES ACTIONS (continued)
C.1 and C.2[In MODE 5 or 6, or]during movement of[recently]
irradiated fuel, if the inoperable CREATCS train cannot be restored to OPERABLE status within the required Completion Time, the OPERABLE CREATCS train must be placed in operation immediately.
This actionensuresthat the remaining train is OPERABLE, that no failures preventing automatic actuation will occur, and that active failures will be readily detected.An alternative to Required Action C.1 is to immediately suspend activities that present a potential for releasing radioactivity that might require isolation of the control room.This places the unit in a condition that minimizes accident risk.This does not preclude the movement of fuel to a safe position.[In MODE 5 or 6, or]during movement of[recently]
irradiated fuel assemblies, with two CREATCS trains inoperable, action must be taken immediately to suspend activities that could result in a release of radioactivity that might require isolation of the control room.This places the unit in a condition that minimizes risk.This does not preclude the movement of fuel to a safe position.If both CREATCS trains are inoperable in MODE 1, 2, 3, or 4, the control room CREATCS may not be capable of performing its intended function.Therefore, LCO 3.0.3 must be entered immediately.
SURVEILLANCE SR 3.7.11.1 REQUIREMENTS REFERENCES This SR verifies thattheheat removal capability of the system is sufficient to remove the heat load assumed in the[safety analyses]in the control room.This SR consists of a combination of testing and calculations.(Ihe
[18]month Frequency is appropriate since significant degradation of the CREATCS is slow and is not expected over this time period.1.FSAR, Section[6.4].WOGSTS B 3.7.11-3 Rev.3.0, 03/31/04 ECCS PREACS B 3.7.12 BASES ACTIONS (continued)
If the ECCS pump room boundary is inoperable, the ECCS PREACS trains cannot perform their intended functions. Actions must be taken to restore an OPERABLE ECCS pump room boundary within 24 hours. During the period that the ECCS pump room boundary is inoperable, appropriate compensatory measures [consistent with the intent, as applicable, of GDC 19, 60, 64 and 10 CFR Part 1001 should be utilized to protect plant personnel from potential hazards such as radioactive contamination, toxic chemicals, smoke, temperature and relative humidity, and physical security. Preplanned measures should be available to address these concerns for intentional and unintentional entry into the condition.
The 24 hour Completion Time is reasonable based on the low probability of a DBA occurring during this time period, and the use of compensatory measures. The 24 hour Completion Time is a typically reasonable time to diagnose, plan and possibly repair, and test most problems with the ECCS pump room boundary.
C.1 and C.2 If the ECCS PREACS train or ECCS pump room boundary cannot be restored to OPERABLE status within the associated Completion Time, the unit must be placed in a MODE in which the LC0 does not apply. To achieve this status, the unit must be placed in at least MODE 3 within 6 hours, and in MODE 5 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required unit conditions from full power conditions in an orderly manner and without challenging unit systems. SURVEILLANCE SR 3.7.12.1 REQUIREMENTS Standby systems should be checked periodically to ensure that they function properly.
As the environment and normal operating conditions on this system are not severe, testing each train once a month provides an adequate check on this system. Monthly heater operations dry out any moisture that may have accumulated in the charcoal from humidity in the ambient air. [Systems with heaters must be operated 210 continuous hours with the heaters energized. Systems without heaters need only be operated for 215 minutes to demonstrate the function of the system.]
Ehe 31 day Frequency is based on the known reliability of equipment and the two train redundancy available.
WOG STS B 3.7.12-4 Rev. 3.0, 03131104 ECCS PREACS B 3.7.12 BASES ACTIONS (continued)
If the ECCS pump room boundary is inoperable, the ECCS PREACS trains cannot perform their intended functions.
Actions must be taken to restore an OPERABLE ECCS pump room boundary within 24 hours.During the period that the ECCS pump room boundary is inoperable, appropriate compensatory measures[consistent with the intent, as applicable, of GDC 19,60,64 and 10 CFR Part 100J should be utilized to protect plant personnel from potential hazards such as radioactive contamination, toxic chemicals, smoke, temperature and relative humidity, and physical security.Preplanned measures should be available to address these concerns for intentional and unintentional entry into the condition.
The 24 hour Completion Time is reasonable based on the low probability of a DBA occurring during this time period, and the use of compensatory measures.The 24 hour Completion Time is a typically reasonable time to diagnose, plan and possibly repair, and test most problems with the ECCS pump room boundary.C.1 and C.2 If the ECCS PREACS train or ECCS pump room boundary cannot be restored to OPERABLE status within the associated Completion Time, the unit must be placed in a MODE in which the LCO does not apply.To achieve this status, the unit must be placed in at least MODE 3 within 6 hours, and in MODE 5 within 36 hours.The allowed Completion Times are reasonable, based on operating experience, to reach the required unit conditions from full power conditions in an orderly manner and without challenging unit systems.SURVEILLANCE SR 3.7.12.1 REQUIREMENTS Standby systems should be checked periodically to ensure that they function properly.As the environment and normaloperatingconditions on this system are not severe, testing each train once a month provides an adequate check on this system.Monthly heater operations dry out any moisture that may have accumulated in the charcoal from humidity in the ambient air.[Systems with heaters must be operated&deg;continuous hours with the heaters energized.
Systems without heaters need only be operated for minutes to demonstrate the function of the system.][he 31 day Frequency is based on the known reliability of equipment and the two train redundancyWOGSTS B 3.7.12-4 Rev.3.0, 03/31/04 ECCS PREACS B 3.7.12 BASES - -- SURVEILLANCE REQUIREMENTS (continued)
This SR verifies that the required ECCS PREACS testing is performed in accordance with the ventilation Filter Testing Program (VFTP)]. The [VFTP] includes testing HEPA filter performance, charcoal adsorbers efficiency, minimum system flow rate, and the physical properties of the activated charcoal (general use and following specific operations). . Specific test Frequencies and additional information are discussed in detail in the WFTP]. This SR verifies that each ECCS PREACS train starts and operates on an actual or simulated actuation signal. Ehe [I81 month Frequency is consistent with that specified in ~efeGnce 4. -nser~ This SR verifies the integrity of the ECCS pump room enclosure. The ability of the ECCS pump room to maintain a negative pressure, with respect to potentially uncontaminated adjacent areas, is periodically tested to verify proper functioning of the ECCS PREACS. During the [post accident] mode of operation, the ECCS PREACS is designed to maintain a slight negative pressure in the ECCS pump room, with respect to adjacent areas, to prevent unfiltered LEAKAGE. The ECCS PREACS is designed to maintain a 5[-0.1251 inches water gauge relative to atmospheric pressure at a flow rate of
[3000] cfm from the ECCS pump room. @e Frequency of (181 months is consistent with the guidance provided in NUREG-0800, Section 6.5.1 (Ref. 6). This test is conducted with the tests for filter penetration; thus, an [I81 month Frequency on a STAGGERED TEST BASIS is consistent with that specified in Reference
: 4. + Operating the ECCS PREACS bypass damper is necessary to ensure that the system functions properly.
The OPERABILITY of the ECCS PREACS bypass damper is verified if it can be ---*-C-. _-_ _Ill.l U --l-- --, _( . ..--- CQ,, [/a rno.ic. ~;P~"'"K'~
;.L ;* &Jccrwr 'i. __IC-------*.
-_*_ ^ *l-*lr".XI^
< WOG STS -- Rev. 3.0, 03/31/04 ECGS PREAGS B 3.7.12 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.7.12.2 This SR verifies that the required EGGS PREAGS testing is performed in accordance with the[Ventilation Filter Testing Program (VFTP)].The[VFTP]includes testing HEPA filter performance, charcoal adsorbers efficiency, minimum system flow rate, and the physical properties of the activated charcoal (general use and following specific operations).
.Specific test Frequencies and additional information are discussed in detail in the[VFTP].SR 3.7.12.3 This SR verifies that each ECGS PREAGS train starts and operates on an actual or simulated actuation signal.{lhe[18J month Frequency is consistent with that specified in Reference 4.W InSCor Z SR 3.7.12.4 This SR verifies the integrity of the EGGS pump room enclosure.
The ability of the EGGS pump room to maintain a negative pressure.with respect to potentially uncontaminated adjacent areas, is periodically tested to verify proper functioning of the EGGS PREACS.During the[post accident]mode of operation, the EGGS PREACS is designed to maintain a slight negative pressure in the EGCS pump room, with respect to adjacent areas, to prevent unfiltered LEAKAGE.The EGGS PREAGS is designed to maintain a:5[-0.125]
inches water gauge relative to atmospheric pressure at a flow rate of[3000}cfm from the ECCS pump room.l!:[1e Frequency of[18]months is consistent with the guidance provided in NUREG-0800, Section 6.5.1 (Ref.6).This test is conducted with the tests for filter penetration; thus, an[18}month Frequency on a STAGGERED TEST BASIS is consistent with that specified in Reference 4.
ylsert.[SR 3.7.12.5 L Fili'''''S t'w1" Ip r$R s,7, I'iS Operating the EGGS PREAGS bypass damper is necessary to ensure that the system functions properly.The OPERABILITY of the EGGS PREACS bypass damper is verified if it can be specified in Reference 4.]
wi:l-l 1 fl1,f'
;'""Re.]ere l1 ce, tf.
.""--------,----,_.,.._-"...,.,.._---_.._-,.._,."-----,,..--
WOG STS B 3.7.12-5 Rev.3.0, 03/31/04 FBACS B 3.7.13 BASES ACTIONS (continued) When two trains of the FBACS are inoperable during movement of [recently] irradiated fuel assemblies in the fuel building, action must be taken to place the unit in a condition in which the LC0 does not apply. Action must be taken immediately to suspend movement of [recently] irradiated fuel assemblies in the fuel building. This does not preclude the movement of fuel to a safe position.
SURVEILLANCE SR 3.7.13.1 REQUIREMENTS Standby systems should be checked periodically to ensure that they function properly. As the environmental and normal operating conditions on this system are not severe, testing each train once every month provides an adequate check on this system.
Monthly heater operation dries out any moisture accumulated in the charcoal from humidity in the ambient air. [Systems with heaters must be operated for 210 continuous hours with the heaters energized. Systems without heaters need only be perated for 215 minutes to demonstrate the function of the system.]
$e 31 day Frequency is based on the known reliability of the equipment and the two train redundancy available.<
-- 7 This SR verifies that the required FBACS testing is performed in accordance with the [Ventilation Filter Testing Program (VFTP)].
The [VFTP] includes testing HEPA filter performance, charcoal adsorber efficiency, minimum system flow rate, and the physical properties of the activated charcoal (general use and following specific operations). Specific test frequencies and additional information are discussed in detail in the [VFTP]. ] [SR 3.7.13.3 This SR verifies that each FBACS train starts and operates on an actual or simulated actuation signal.ahe
[18] month Frequency is consistent with Reference
: 6. ] WOG STS B 3.7.13-5 Rev. 3.0, 03131104 FBACS B 3.7.13 BASES ACTIONS (continued)
When two trains of the FBACS are inoperable during movement of[recently]
irradiated fuel assemblies in the fuel building, action must be taken to place the unit in a condition in which the LCO does not apply.Action must be taken immediately to suspend movement of[recently]
irradiated fuel assemblies in the fuel building.This does not preclude the movement of fuel to a safe position.[SR 3.7.13.2 SURVEILLANCE REQUIREMENTS SR 3.7.13.1 Standby systems should be checked periodically to ensure that they function properly.As the environmental and normal operating conditions on this system are not severe, testing each train once every month provides an adequate check on this system.Monthly heater operation dries out any moisture accumulated in the charcoal from humidity in the ambient air.[Systems with heaters must be operated for 0 continuous hours with the heaters energized.
Systems without heaters need only for minutes to demonstrate the function of the system.]fIhe 31 day Frequency is based on the known reliability of the equipment and the two train(I;1S;r{i)-This SR verifies that the required FBACS testing is performed in accordance with the[Ventilation Filter Testing Program (VFTP)).The[VFTP]includes testing HEPA filter performance, charcoal adsorber efficiency, minimum system flow rate, and the physical properties of the activated charcoal (general use and following specific operations).
Specific test frequencies and additional information are discussed in detail in the[VFTP].][SR 3.7.13.3 This SR verifies that each FBACStrain starts and operates on an actual or simulated actuation signal.U"he
[18]month Frequency is consistent with Reference 6.J WOG STS B 3.7.13-5 Rev.3.0, 03/31/04 FBACS B 3.7.13 BASES SURVEILLANCE REQUIREMENTS (continued)
This SR verifies the integrity of the fuel building enclosure. The ability of the fuel building to maintain negative pressure with respect to potentially uncontaminated adjacent areas is periodically tested to verify proper function of the FBACS. During the [post accident]
mode of operation, the FBACS is designed to maintain a slight negative pressure in th-e fuel building, to prevent unfiltered LEAKAGE. The FBACS is designed to maintain a S[-0.1251 inches water gauge with respect to at pressure at a flow rate of [20,000] cfm to the fuel building.
r:heric Frequency of [I81 months is consistent with the guidance provided in NUREG-0800, Section 6.5.1 (Ref. 7). An [I81 month Frequency (on a STAGGERED TEST BASIS) is consistent with Reference
: 6. 6-----, _I___--*" [SR 3.7.13.5 Operating the FBACS filter bypass damper is necessary to ensure that the system functions properly.
The OPERABILITY of the FBACS filter bypass damper is verified if it can be closed. En [I81 month Frequency is consistent with Reference J -~~~ 1 -' -.* " * "' " " lYt, , - * *,,,.y REFERENCES
: 1. FSAR, Section
[6.5.1]. Cme~t 2) 2. FSAR, Section
[9.4.5]. 3. FSAR, Section [I 5.7.41. 4. Regulatory Guide 1.25.
: 5. 10 CFR 100. 6. Regulatory Guide I .52, Rev. [2]. 7. NUREG-0800, Section 6.5.1, Rev. 2, July 1981. WOG STS Rev. 3.0, 03131104 FBACS B 3.7.13 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.7.13.4 This SR verifies th.e integrity of the fuel building enclosure.
The ability of the fuel building to maintain negative pressure with respect to potentially uncontaminated adjacent areas is periodically tested to verify proper function of the FBACS.During the[post accident]mode of operation, the FBACS is designed to maintain a slight negative pressure in the fuel building, to prevent unfiltered LEAKAGE.The FBACS is designed to maintain a=:;[-0.125]
inches water gauge with respect to pressure at a flow rate of[20,000]cfm to the fuel building.L0e Frequency of[18]months is consistent with the guidance provided in NUREG-0800, Section 6.5.1 (Ref.7).An[18]month Frequency (on a STAGGERED TEST BASIS)is consistent with Reference 6..."".....
[SR 3.7.
 
==13.5 REFERENCES==
Operatingthe FBACS filter bypass damper is necessary to ensure that the system functions properly.The OPERABILITY of the FBACS filter bypass damper is verified if it can be closed.[18]month Frequency is consistent with Reference 6J 1.FSAR, Section[6.5.1]...l,*******..*_"**,******,*,,,*.........-CE[;eV'rn---,i...=-..-.
-2, FSAR, Section[9.4.5].3.FSAR, Section[15.7.4].4.Regulatory Guide 1.25.5.10 CFR 100.6.Regulatory Guide 1.52, Rev.[2].7.NUREG-0800, Section 6.5.1, Rev.2, JUly 1981.WOGSTS B 3.7.13-6 Rev.3.0, 03/31/04 PREACS B 3.7.14 BASES . .. . ACTIONS (continued)
C.l and C.2 If the inoperable train or penetration room boundary cannot be restored to OPERABLE status within the associated Completion Time, the unit must be placed in a MODE in which the LC0 does not apply. To achieve this status, the unit must be placed in at least MODE 3 within 6 hours, and in MODE 5 within 36 hours. The Completion Times are reasonable, based on operating experience, to reach the required unit conditions from full power conditions in an orderly manner and without challenging unit systems. SURVEILLANCE SR 3.7.14.1 REQUIREMENTS Standby systems should be checked periodically to ensure that they function properly. As the environmental and normal operating conditions on this system are not severe, testing each train once every month provides an adequate check on this system. Monthly heater operation dries out any moisture that may have accumulated in the charcoal as a result of humidity in the ambient air. [Systems with heaters must be operated for 210 continuous hours with the heaters energized. Systems without heaters need only be operated for 215 minutes to demonstrate the function of the system.]
Ehe 31 day Frequency is based on the known reliability of equipment and the two train redundancy available.
f7 This SR verifies that the required PREACS testing is performed in accordance with the [Ventilation Filter Testing Program (VFTP)]. The
[VFTP] includes testing HEPA filter performance, charcoal adsorber efficiency, minimum system flow rate, and the physical properties of the activated charcoal (general use and following specific operations). Specific test frequencies and additional information are discussed in detail in the WFTP]. This SR verifies that each PREACS starts and operates on an actual or simulated actuation signal.Ghe
[18] month Frequency is consistent with that specified in Reference WOG STS B 3.7.14-4 Rev. 3.0, 03/31/04 PREACS B 3.7.14 BASES ACTIONS (continued)
C.1 and C.2 If the inoperable train or penetration room boundary cannot be restored to OPERABLE status within the associated Completion Time, the unit must be placed in a MODE in which the LCO does not apply.To achieve this status, the unit must be placed in at least MODE 3 within 6 hours, and in MODE 5 within 36 hours.The Completion Times are reasonable, based on operating experience, to reach the required unit conditions from full power conditions in an orderly manner and without challenging unit systems.SR 3.7.14.2 SURVEILLANCE REQUIREMENTS SR 3.7.14.1 Standby systems should be checked periodically to ensure that they function properly.As the environmental and normal operating conditions on this system are not severe, testing each train once every month provides an adequate check on this system.Monthly heater operation dries out any moisture that may have accumulated in the charcoal as a result of humidity in the ambient air.[Systems with heaters must be operated for 0 continuous hours with the heaters energized.
Systems without heaters need only be operated for minutes to demonstrate the function of the system.][fhe 31 day Frequency is based on the known reliability of equipment and the two train redundancy available.
This SR verifies that the required PREACS testing is performed in accordance with the[Ventilation Filter Testing Program (VFTP)].The[VFTP]includes testing HEPA filter performance, charcoal adsorber efficiency, minimum system flow rate, and the physical properties of the activated charcoal (general use and following specific operations).
Specific test frequencies and additional information are discussed in detail in the[VFTP].[SR 3.7.14.3 This SR verifies that each PREACS starts and operates on an actual or simulated actuation signal.Uhe
[18]month Frequency is consistent with that specified in Reference St.].f2;)h5eY" 2..WOG STS B 3.7.14-4 Rev.3.0, 03/31/04 PREACS B 3.7.14 BASES SURVEILLANCE REQUIREMENTS (continued)
[SR 3.7.14.4 This SR verifies the integrity of the penetration room enclosure. The ability of the penetration room to maintain a negative pressure, with respect to potentially uncontaminated adjacent areas, is periodically tested to verify proper function of PREACS. During the [post accident]
mode of operation, the PREACS is designed to maintain a 51-0.1251 inches water gauge relative to atmospheric pressure at a flow rate of [3000] cfm to prevent penetration room area, and provides sufficientair velocity to transport particulate contaminants, assuming only one filter train is operating.
The number of filter elements is selected to limit the flow rate through any individual element to about [3000] cfm. This may vary based on filter housing geometry. The maximum limit ensures that the flow through, and pressure drop across, each filter element are not excessive. The number and depth of the adsorber elements ensure that, at the maximum flow rate, the residence time of the air stream in the charcoal bed achieves the desired adsorption rate.
At least a [0.125] second residence time is necessary for an assumed [99]% efficiency.
The filters have a certain pressure drop at the design flow rate when clean. The magnitude of the pressure drop indicates acceptable performance, and is based on manufacturers' recommendations for the filter and adsorber elements at the design flow rate.
An increase in pressure drop or a decrease in flow indicates that the filter is being loaded or that there are other problems with the system.
Ehis test is conducted along with the tests for filter penetration; thus, the [I81 month Frequency is consistent with that specified in Reference
[SR 3.7.14.5 It is necessary to operate the PREACS filter bypass damper to ensure that the system functions properly.
The OPERABILITY of the PREACS filter bypass damper is verified if it can be closed. An [I 81 month E Frequency is consistent with that specified in Reference
: 5. ] 6, WOG STS Rev. 3.0, 03/31/04 PREACS B 3.7.14 BASES SURVEILLANCE REQUIREMENTS (continued)
[SR 3.7.14.4 This SR verifies the integrity of the penetration room enclosure.
The ability of the penetration room to maintain a negative pressure, with respect to potentially uncontaminated adjacent areas, is periodically tested to verify proper function of PREACS.During the[post accident]mode of operation, the PREACS is designedtomaintain a S[-0.125]inches water gauge relative to atmospheric pressure at a flow rate of[3000]cfm in the penetration room with res ect to adjacent areas to prevent unfiltered Frequency of[18]mont s is
...f y The minimum system flow rate maintains a slight negative penetration room area, and provides sufficient air velocity to transport particulate contaminants, assuming only one filter train is operating.
The number of filter elements is selected to limit the flow rate through any individual element to about[3000]cfm.This may vary based on filter housing geometry.The maximum limitensuresthat the flow through, and pressure drop across, each filter element are not excessive.
The number and depth of the adsorber elements ensure that, at the maximum flow rate, the residence time of the air stream in the charcoal bed achieves the desired adsorption rate.At least a[0.125]second residence time is necessary for an assumed[99]%efficiency.
The filters have a certain pressure drop at the design flow rate when clean.The magnitude of the pressure drop indicates acceptable performance, and is based on manufacturers' recommendations for the filter and adsorber elements at the design flow rate.An increase in pressure drop or a decrease in flow indicates that the filter is being loaded or that there are other problems with the system.Uhis test is conducted along with the tests for filter penetration; thus, the[18]month Frequency is consistent with that specified in Reference 5.][SR 3.7.14.5 It is necessary to operate the PREACS filter bypass damper to ensure that the system functions properly.The OPERABILITY of the PREACS filter bypass damper is verified if it can be closed.[18]month Frequency is consistent with that specified in Reference 5.]*.-_......-._....(l.h-Sc;;r+3J WOGSTS B 3.7.14-5 Rev.3.0, 03/31/04 Fuel Storage Pool Water Level B 3.7.15 BASES APPLICABILITY This LC0 applies during movement of irradiated fuel assemblies in the fuel storage pool, since the potential for a release of f ssion products exists. ACTIONS - A. 1 Required Action A.1 is modified by a Note indicating that LC0 3.0.3 does not apply. When the initial conditions for prevention of an accident cannot be met, steps should be taken to preclude the accident from occurring. When the fuel storage pool water level is lower than the required level, the movement of irradiated fuel assemblies in the fuel storage pool is immediately suspended to a safe position. This action effectively precludes the occurrence of a fuel handling accident. This does not preclude movement of a fuel assembly to a safe position. If moving irradiated fuel assemblies while in MODE 5 or 6, LC0 3.0.3 would not specify any action. If moving irradiated fuel assemblies while in MODES I, 2, 3, and 4, the fuel movement is independent of reactor operations. Therefore, inability to suspend movement of irradiated fuel assemblies is not sufficient reason to require a reactor shutdown.
SURVEILLANCE SR 3.7.15.1 REQUIREMENTS This SR verifies sufficient fuel storage pool water is available in the event of a fuel handling accident The water level in the fuel storage pool must be checked periodically.
Ehe 7 day Frequency is appropriate because the volume in the pool is normally stable. Water level changes are controlled by plant procedures and are acceptable based on operating -I*- experience.
+, ,. 4P& During refueling operations, the level in the fuel storage pool is in equilibrium with the refueling canal, and the level in the refueling canal is checked daily in accordance with SR 3.9.6.1. REFERENCES
: 1. FSAR, Section [9.1.2]. 2. FSAR, Section L9.1.31. 3. FSAR, Section [15.7.4].
: 4. Regulatory Guide 1 .Z5, [Rev. 01. 5. 10CFRl00.11.
WOG STS Rev. 3.0, 03/31/04 BASES APPLICABILITY ACTIONS SURVEILLANCE REQUIREMENTS Fuel Storage Pool Water Level B 3.7.15 This LCO applies during movement of irradiated fuel assemblies in the fuel storage pool, since the potential for a release of fission products exists.Required Action A.1 is modified by a Note indicating that LCO 3.0.3 does not apply.When the initial conditions for prevention of an accident cannot be met, steps should be taken to preclude the accident from occurring.
When the fuel storage pool water level is lower than the required level, the movement of irradiated fuel assemblies in the fuel storage pool is immediately suspended to a safe position.This action effectively precludes the occurrence of a fuel handling accident.This does not preclude movement of a fuel assembly to a safe position.If moving irradiated fuel assemblies while in MODE 5 or 6, LCO 3.0.3 would not specify any action.If moving irradiated fuel assemblies while in MODES 1, 2, 3, and 4, the fuel movement is independent of reactor operations.
Therefore, inability to suspend movement of irradiated fuel assemblies is not sufficient reason to require a reactor shutdown.SR 3.7.15.1 This SR verifies sufficient fuel storage pool water is available in the event of a fuel handling The water level in the fuel storage pool must be checked periodically.
LIhe 7 day Frequency is appropriate because the volume in the pool is normally stable.Water level changes arecontrolled by plant procedures and are acceptable based on operating experience.
During refueling operations, the level in the fuel storage pool is in equilibrium with the refueling canal, and the level in the refueling canal is checked daily in accordance with SR 3.9.6.1.REFERENCES 1.FSAR, Section[9.1.2].2.FSAR, Section[9.1.3J.3.FSAR, Section[15.7.4].4.Regulatory Guide 1.25,[Rev.0].5.10CFR100.11.
WOGSTS 83.7.15-2 Rev.3.0, 03/31/04
[Fuel Storage Pool Boron Concentration]
B 3.7.16 BASES ACTIONS (continued)
When the concentration of boron in the fuel storage pool is less than required, immediate action must be taken to preclude the occurrence of an accident or to mitigate the consequences of an accident in progress.
This is most efficiently achieved by immediately suspending the movement of fuel assemblies. The concentration of boron is restored simultaneously with suspending movement of fuel assemblies. Alternatively, beginning a verification of the fuel storage pool fuel locations, to ensure proper locations of the fuel, can be performed. However, prior to resuming movement of fuel assemblies, the concentration of boron must be restored. This does not preclude movement of a fuel assembly to a safe position. If the LC0 is not met while moving irradiated fuel assemblies in MODE 5 or 6, LC0 3.0.3 would not be applicable.
If moving irradiated fuel assemblies while in MODE 1, 2, 3, or 4, the fuel movement is independent of reactor operation. Therefore, inability to suspend movement of fuel assemblies is not sufficient reason to require a reactor shutdown.
SURVEILLANCE SR 3.7.16.1 REQUIREMENTS This SR verifies that the concentration of boron in the fuel storage pool is within the required limit.
As Ion as this SR is met, the analyzed accidents are fully addressed.
f The 7 day Frequency is appropriate because no major replenishment of pool over such a short period of time. < --,, REFERENCES
[ 1. Callaway FSAR, Appendix 9.1A, "The Maximum Density Rack (MDR) Design Concept." 2. Description and Evaluation for Proposed Changes to Facility Operating Licenses DPR-39 and DPR-48 (Zion Power Station).
] 3. Double contingency principle of ANSI N16.1-1975, as specified in the April 14, 1978 NRC letter (Section 1.2) and implied in the proposed revision to Regulatory Guide 1.13 (Section 1.4, Appendix A).
: 4. FSAR, Section [15.7.4].
WOG STS Rev. 3.0, 03/31/04 [Fuel Storage Pool Boron Concentration]
B 3.7.16 BASES ACTIONS (continued)
When the concentration of boron in the fuel storage pool is less than required, immediate action must be taken to preclude the occurrence of an accident or to mitigate the consequences of an accident in progress.This is most efficiently achieved by immediately suspending the movement of fuel assemblies.
The concentration of boron is restored simultaneously with suspending movement of fuel assemblies.
Alternatively, beginning a verification of the fuel storage pool fuel locations, to ensure proper locations of the fuel, can be performed.
However, prior to resuming movement of fuel assemblies, the concentration of boron must be restored.This does not preclude movement of a fuel assembly to a safe position.If the LCO is not met while moving irradiated fuel assemblies in MODE 5 or 6, LCO 3.0.3 would not be applicable.
If moving irradiated fuel assemblies while in MODE 1, 2, 3, or 4, the fuel movement is independent of reactor operation.
Therefore, inability to suspend movement of fuel assemblies is not sufficient reason to require a reactor shutdown.SURVEILLANCE SR 3.7.16.1 REQUIREMENTS This SR verifies that the concentration of boron in the fuel storage pool is within the required limit.Asas this SR is met, the analyzed accidents are fully addressed.LJhe 7 day Frequency is appropriate because no major replenishment of pool water is expected to take place over such a short period of time.
....:lIlo!-_REFERENCES
[1.Callaway FSAR, Appendix 9.1A,"The Maximum Density Rack (MDR)Design Concept." 2.Description and Evaluation for Proposed Changes to Facility Operating Licenses DPR-39 and DPR-48 (Zion Power Station).]3.Double contingency principle of ANSI N16.1-1975, as specified in the April 14, 1978 NRC letter (Section 1.2)and implied in the proposed revision to Regulatory Guide1.13(Section 1.4, Appendix A).4.FSAR, Section[15.7.4].WOGSTS B 3.7.16-3 Rev.3.0, 03/31/04 Secondary Specific Activity B 3.7.18 BASES ACTIONS A.l and A.2 DOSE EQUIVALENT 1-131 exceeding the allowable value in the secondary coolant, is an indication of a problem in the RCS and contributes to increased post accident doses. If the secondary specific activity cannot be restored to within limits within the associated Completion Time, the unit must be placed in a MODE in which the LC0 does not apply. To achieve this status, the unit must be placed in at least MODE 3 within 6 hours, and in MODE 5 within 36 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required unit conditions from full power conditions in an orderly manner and without challenging unit systems. SURVEILLANCE SR 3.7.18.1 REQUIREMENTS This SR verifies that the secondary specific activity is within the limits of the accident analysis.
A gamma isotopic analysis of the secondary coolant, which determines DOSE EQUIVALENT 1-131, confirms the validity of the safety analysis assumptions as to the source terms in post accident releases.
It also serves to identify and trend any unusual isotopic concentrations that might indicate changes in reactor coolant activity or LEAKAGE. The 31 day Frequency is based on the detection of increasing trends of the < eve1 of DOSE EQUIVALENT 1-131, and allows for appropriate action to be taken to maintain levels below REFERENCES 1.
10CFR100.11.
: 2. FSAR, Chapter 11 51. WOG STS Rev. 3.0, 03/31/04 BASES ACTIONS SURVEILLANCE REQUIREMENTS REFERENCES Secondary Specific Activity B 3.7.18 A.1 and A.2 DOSE EQUIVALENT 1-131 exceeding the allowable value in the secondary coolant, is an indication of a problem in the RCS and contributes to increased post accident doses.If the secondary specific activity cannot be restored to within limits within the associated Completion Time, the unit must be placed in a MODE in which the LCO does not apply.To achieve this status, the unit must be placed in at least MODE 3 within 6 hours, and in MODE 5 within 36 hours.The allowed Completion Times are reasonable, based on operating experience, to reach the required unit conditions from full power conditions in an orderly manner and without challenging unit systems.SR 3.7.18.1 This SR verifies that the secondary specific activity is within the limits of the accident analysis.A gamma isotopic analysis of the secondary coolant.which determines DOSE EQUIVALENT 1-131, confirms the validity of the safety analysis assumptions as to the source terms in post accident releases.It also serves to identify and trend any unusual isotopic concentrations that might indicate changes in reactor coolant activity or LEAKAGE.lThe 31 day Frequency is based on the detection of increasing trends of DOSE EQUIVALENT I M 131, and allows for appropriate action to be taken to maintain levels below the LCO limit. 1.10 CFR 100.11.2.FSAR, Chapter[15}.WOGSTS B 3.7.18-3 Rev.3.0, 03/31/04 BASES - SURVEILLANCE REQUIREMENTS (continued) voltages. The specified minimum and maximum frequencies of the DG are 58.8 Hz and 61.2 Hz, respectively.
These values are equal to f 2% of the 60 Hz nominal frequency and are derived from the recommendations given in Regulatory Guide 1.9 (Ref.
3). This SR ensures proper circuit continuity for the offsite AC electrical power supply to the onsite distribution network and availability of offsite AC electrical power. The breaker alignment verifies that each breaker is in its correct position to ensure that distribution buses and loads are connected to their preferred power source, and that appropriate independence of offsite circuits is maintained.
@e 7 day Frequency is adequate since breaker position is not likely to change without the operator being aware of it and because its status is displayed in the control room. t..,. (T- SR 3.8.1.2 and SR 3.8.1.7 These SRs help to ensure the availability of the standby electrical power supply to mitigate DBAs and transients and to maintain the unit in a safe shutdown condition. To minimize the wear on moving parts that do not get lubricated when the engine is not running, these SRs are modified by a Note (Note 1 for SR 3.8.1.2 and Note for SR 3.8.1.7) to indicate that all DG starts for these Surveillances may be preceded by an engine prelube period and followed by a warmup period prior to loading. For the purposes of SR 3.8.1.2 and SR 3.8.1.7 testing, the DGs are started from standby conditions.
Standby conditions for a DG mean that the diesel engine coolant and oil are being continuously circulated and temperature is being maintained consistent with manufacturer recommendations.
[ In order to reduce stress and wear on diesel engines, some manufacturers recommend a modified start in which the starting speed of DGs is limited, warmup is limited to this lower speed, and the .DGs are gradually accelerated to synchronous speed prior to loading. These start procedures are the intent of Note 2, which is only applicable when such modified start procedures are recommended by the manufacturer.
] WOG STS -. - - Rev. 3.1. 12/01/05 BASES SURVEILLANCE REQUIREMENTS (continued) voltages.The specified minimum and maximum frequencies of the DG are 58.8 Hz and 61.2 Hz, respectively.
These values are equal to+/-2%of the 60 Hz nominal frequency and are derived from the recommendations given in Regulatory Guide 1.9 (Ref.3).SR 3.8.1.1 This SR ensures proper circuit continuity for the offsite AC electrical power supply to the onsite distribution network and availability of offsite AC electrical power.The breaker alignment verifies that each breaker is in its correct position to ensure that distribution buses and loads are connected to their preferred power source, and that appropriate independence of offsite circuits is maintained.
[be 7 day Frequency is adequate since breaker position is not likely to change without the operator being aware of it and because its status is displayed in the control room.@SR 3.8.1.2 and SR 3.8.1.7 These SRs help to ensure the availability of the standby electrical power supply to mitigate DBAs and transients and to maintain the unit in a safe shutdown condition.
To minimize the wear on moving parts that do not get lUbricated when the engine is not running, these SRs are modified by a Note (Note 1 for SR 3.8.1.2 and Note for SR 3.8.1.7)to indicate that all DG starts for these Surveillances may be preceded by anengineprelube period and followed by a warmup period prior to loading.For the purposes of SR 3.8.1.2 and SR 3.8.1.7 testing, the DGs are started from standby conditions.
Standby conditions for a DG mean that the diesel engine coolant and oil are being continuously circulated and temperature is being maintained consistent with manufacturer recommendations.
[In order to reduce stress and wear on diesel engines, some manufacturers recommend a modified start in which the starting speed of DGs is limited, warmup is limited to this lower speed, and the DGs are gradually accelerated to synchronous speed prior to loading.These start procedures are the intent of Note 2, which is only applicable when such modified start procedures are recommended bythemanufacturer.
]WOGSTS B 3.8.1-13 Rev.3.1,12/01/05 BASES SURVEILLANCE REQUIREMENTS (continued) SR 3.8.1.7 requires that(d4 d#requ~$he DG starts from standby conditions and achieves required volrag and frequency within 10 seconds. The I0 second start requirement
&~~~orts the asshptions of the design basis LOCA analysis in the FSAR, Chapter [I51 (Ref. 5). The 10 second start requirement is not applicable to SR 3.8.1.2 (see Note 2) when a modified start procedure as described above is used. If a modified start is not used, the 10 second start requirement of SR 3.8.1.7 applies. Since SR 3.8.1.7 requires a 10 second start, it is more restrictive than SR 3.8.1.2, and it may be performed in lieu of SR 3.8.1.2. In addition to the SR requirements, the time for the DG to reach steady state operation, unless the modified DG start method is employed, is periodically monitored and the trend evaluated to identify degradation of governor and voltage regulator performance.
r~he 31 day Frequency for SR 3.8.1.2 is consistent with Regulatory Guide 1.9 (Ref. 3). The 184 day Frequency for SR 3.8.1.7 is a reduction in cold testing consistent with Generic Letter 84-15 (Ref. 7). These Frequencies provide adequate assurance of DG OPERABILITY, while minimizing degradation resulting from testing.
%rcf3) This Surveillance verifies that the DGs are capable of synchronizing with the offsite electrical system and accepting loads greater than or equal to the equivalent of the maximum expected accident loads. A minimum run time of 60 minutes is required to stabilize engine temperatures, while minimizing the time that the DG is connected to the offsite source. Although no power factor requirements are established by this SR, the DG is normally operated at a power factor between
[0.8 lagging] and [1.0]. The [0.8] value is the design rating of the machine, while the
[I .O] is an operational limitation [to ensure circulating currents are minimized].
The load band is provided to avoid routine overloading of the DG. Routine overloading may result in more frequent teardown inspections in accordance with vendor recommendations in order to maintain DG OPERABILITY.
Ee 31 day Frequency for this Surveillance is consistent with Regulatory Guide 1.9 (Ref. 3). -.".I- -I-.IYU1l WOG STS B 3.8.1-14 Rev. 3.1, 12/01/05 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.8.1.7 requires d02e q u=)the DG starts from standby conditions and ac;eves required voage and frequency within 10 seconds.The 10 second start requirement supports the assumptions of the design basis LOCA analysis in the FSAR, Chapter[15](Ref.5).The 10 second start requirement is not applicable to SR 3.8.1.2 (see Note 2)when a modified start procedure as described above is used.If a modified start is not used, the 10 second start requirement of SR 3.8.1.7 applies.Since SR 3.8.1.7 requires a 10 second start, it is more restrictive than SR 3.8.1.2, and it may be performed in lieu of SR 3.8.1.2.In addition to the SR requirements, the time for the DG to reach steady state operation, unless the modified DG start method is employed, is periodically monitored and the trend evaluated to identify degradation of governor and voltage regulator performance.
[The 31 day Frequency for SR 3.8.1.2 is consistent with Regulatory Guide 1.9 (Ref.3).The 184 day Frequency for SR 3.8.1.7 is a reduction in cold testing consistent with Generic Letter 84-15 (Ref.7).These Frequencies provide adequate assurance of DG OPERABILITY, while minimizing degradation reSUlting from
.;,SR 3.8.1.3 This Surveillance verifies that the DGs are capable of synchronizing with the offsite electrical system and accepting loads greater than or equal to the equivalent of the maximum expected accident loads.A minimum run time of 60 minutes is required to stabilize engine temperatures, while minimizing the time that the DG is connected to the offsite source.Although no power factor requirements are established by this SR, the DG is normally operated at a power factor between[0.8 lagging]and[1.0].The[0.8]value is the design rating of the machine, while the[1.0]is an operational limitation
[to ensure circulating currents are minimized].
The load band is provided to avoid routine overloading of the DG.Routine overloading may result in more frequent teardown inspections in accordance with vendor recommendations in order to maintain DG OPERABILITY. 31 day Frequency for this Surveillance is consistent with Regulatory Guide 1.9 (Ref.3)..(;:'."..*._..
z)WOGSTS B 3.8.1-14 Rev.3.1, 12/01/05 BASES SURVEILLANCE REQUIREMENTS (continued)
This SR is modified by four Notes. Note I indicates that diesel engine runs for this Surveillance may include gradual loading, as recommended by the manufacturer, so that mechanical stress and wear on the diesel engine are minimized. Note 2 states that momentary transients, because of changing bus loads, do not invalidate this test. Similarly, momentary power factor transients above the limit do not invalidate the test. Note 3 indicates that this Surveillance should be conducted on only one DG at a time in order to avoid common cause failures that might result from offsite circuit or grid perturbations. Note 4 stipulates a prerequisite requirement for performance of this SR. A successful DG start must precede this test to credit satisfactory performance. This SR provides verification that the level of fuel oil in the day tank [and engine mounted tank] is at or above the level at which fuel oil is automatically added. The level is expressed as an equivalent volume in gallons, and is selected to ensure adequate fuel oil for a minimum of 1 hour of DG operation at full load plus 10%.
Ge 31 day Frequency is adequate to assure that a sufficient supply of fuel oil is available, since low level alarms are provided and facility operators would be aware of any large uses of fuel oil during this period.+, Microbiological fouling is a major cause of fuel oil degradation. There are numerous bacteria that can grow in fuel oil and cause fouling, but all must have a water environment in order to survive. Removal of water from the fuel oil day [and engine mounted]
tanks~nce~very~1_1~liminates the necessary environment for bacterial survival. This is the most effective means of controlling microbiological fouling. In addition, it eliminates the potential for water entrainment in the fuel oil during DG operation. Water may come from any of several sources, including condensation, ground water, rain water, contaminated fuel oil, and breakdown of the fuel oil by bacteria. Frequent checking for and removal of accumulated water minimizes fouling and provides data watertight integrity of the fuel oil system.~he Surveillance are established by Regulatory Guide 1.137 (Ref. 10). This preventative maintenance.
flhe presence of water does not necessarily represent failure of this SR, provided the accumulated water is removed during the performance of this Surveiliance.
WOG STS B 3.8.1-1 5 Rev. 3.1, 12/01/05 SR 3.8.1.5 BASES SURVEILLANCE REQUIREMENTS (continued)
This SR is modified by four Notes.Note 1 indicates that diesel engine runs for this Surveillance may include gradual loading, as recommended by the manufacturer, so that mechanical stress and wear on the diesel engine are minimized.
Note 2 states that momentary transients, because of changing bus loads, do not invalidate this test.Similarly, momentary power factor transients above the limit do not invalidate the test.Note 3 indicates that this Surveillance should be conducted on only one DG at a time in order to avoid common cause failures that might result from offsite circuit or grid perturbations.
Note 4 stipulates a prerequisite requirement for performance of this SR.A successful DG start must precede this test to credit satisfactory performance.
SR 3.8.1.4 This SR provides verification that the level of fuel oil in the day tank[and engine mounted tank]is at or above the level at which fuel oil is automatically added.The level is expressed as an equivalent volume in gallons, and is selected to ensure adequate fuel oil for a minimum of 1 hour of DG operation at full load plus 10%.[[he 31 day Frequency is adequate to assure that a sufficient supply of fuel oil is available, since low level alarms are provided and facility operators would be aware of any large uses of fuel oil Microbiological fouling is a major cause of fuel oil degradation.
There are numerous bacteria that can grow in fuel oil and cause fouling, but all must have a water environment in order to survive.Removal of water from the fuel oil day[and engine mounted]
the necessary environment for bacterial survival.This is the most effective means of controlling microbiological fouling.In addition, it eliminates the potential for water entrainment in the fuel oil during DG operation.
Water may come from any of several sources, including condensation, ground water, rain water, contaminated fuel oil, and breakdown of the fuel oil by bacteria.Frequent checking for and removal of accumulated water minimizes fouling and provides data regardingwatertight integrity of the fuel oil system.[fhe Surveillanced 31 are established by Regulatory Guide 1.137 (Ref.10).This SR is for reventative maint ance.he presence of water does not necessarily represent failure of this SR, provided the accumulated water is removed during the performance of this Surveillance.
WOG STS 83.8.1-15 Rev.3.1,12/01/05 BASES SURVEILLANCE REQUIREMENTS (continued) This Surveillance demonstrates that each required fuel oil transfer pump operates and transfers fuel oil from its associated storage tank to its associated day tank. This is required to support continuous operation of standby power sources. This Surveillance provides assurance that the fuel oil transfer pump is OPERABLE, the fuel oil piping system is intact, the fuel delivery piping is not obstructed, and the controls and control systems for automatic fuel transfer systems are OPERABLE.
[ The Frequency for this SR is variable, depending on individual system design, with up to a [92] day interval.
The [92] day Frequency corresponds to the testing requirements for pumps as contained in the ASME Code (Ref.
11); however, the design of fuel transfer systems is such that pumps operate automatically or must be started manually in order to maintain an adequate volume of fuel oil in the day [and engine mounted] tanks during or following DG testing. In such a case, a 31 day Frequency is appropriate. Since proper operation of fuel transfer systems is an inherent part of DG OPERABILITY, the Frequency of this SR should be modified to reflect individual designs,y See SR 3.8.1.2. Transfer of each [4.16 kV ESF bus] power supply from the normal offsite circuit to the alternate offsite circuit demonstrates the OPERABILITY of the alternate circuit distribution network to power the shutdown loads. nhe [I8 month] Frequency of the Surveillance is based on engineering judgment, taking into consideration the unit conditions required to perform the Surveillance, and is intended to be consistent with expected fuel cycle lengths. Operating experience has shown that these components usually pass the SR when performed at the
[I8 month] Frequency. Therefore, the Frequency was concluded to be acce~table from a reliabilitv This SR is modified by a Note. The reason for the Note is that, during operation with the reactor critical, performance of this SR could cause perturbations to the electrical distribution systems that could challenge continued steady state operation and, as a result, unit safety systems. This restriction from normally performing the Surveillance in MODE I or 2 WOG STS B 3.8.1-16 Rev. 3.1, 12/01/05 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.8.1.6 This Surveillance demonstrates that each required fuel oil transfer pump operates and transfers fuel oil from its associated storage tank to its associated day tank.This is required to support continuous operation of standby power sources.This Surveillance provides assurance that the fuel oil transfer pump is OPERABLE, the fuel oil piping system is intact, the fuel delivery piping is not obstructed, and the controls and control systems for automatic fuel transfer systems are OPERABLE.[The Frequency for this SR is variable, depending on individual system design, with up to a[92]day interval.The[92]day Frequency corresponds to the testing requiremenfs for pumps as contained in the ASME Code (Ref.11);however, the design of fuel transfer systems is such that pumps operate automatically or must be started manually in order to maintain an adequate volume of fuel oil in the day[and engine mounted]tanks during or following DG testing.In such a case, a 31 day Frequency is appropriate.
Since proper operation of fuel transfer systems is an inherent part of DG OPERABILITY, the Frequency of this SR should be modified to reflect individual designs.y---
SR 3.8.1.7 See SR 3.8.1.2.[SR 3.8.1.8 Transfer of each[4.16 kV ESF bus]power supply from the normal offsite circuit to the alternate offsite circuit demonstrates the OPERABILITY of the alternatecircuitdistribution network to power the shutdown loads.U-he[18 month)Frequency of the Surveillance is based on engineering judgment, taking into consideration the unit conditions required to perform the Surveillance, and is intended to be consistent with expected fuel cycle lengths.Operating experience has shown that these components usually pass the SR when performed at the[18 month]Frequency.
Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.
This SR is modified by a Note.The reason for the Note is that, during operation with the reactor critical, performance of this SR could cause perturbations to the electrical distribution systems that could challenge continued steady state operation and, as a result, unit safety systems.This restriction from normally performing the Surveillance in MODE 1 or 2 WOGSTS B 3.8.1-16 Rev.3.1,12/01/05 BASES SURVEILLANCE REQUIREMENTS (continued) sequencing of the largest load. The voltage and frequency specified are consistent with the design range of the equipment powered by the DG. SR 3.8.1.9.a corresponds to the maximum frequency excursion, while SR 3.8.1.9.b and SR 3.8.1.9.c are steady state voltage and frequency values to which the system must recover following load rejection.che 11 8 month] Frequency is consistent with the recommendation of ~e~ulatory
~uide I .lo8 (Ref. 9). .+--_ Gz'GEJ This SR is modified by two Notes.
The reason for Note 1 is that during operation with the reactor critical, performance of this SR could cause perturbations to the electrical distribution systems that could challenge continued steady state operation and, as a result, unit safety systems. This restriction from normally performing the Surveillance in MODE 1 or 2 is further amplified to allow the Surveillance to be performed for the purpose of reestablishing OPERABILITY (e.g., post work testing following corrective maintenance, corrective modification, deficient or incomplete surveillance testing, and other unanticipated OPERABILITY concerns) provided an assessment determines plant safety is maintained or enhanced. This assessment shall, as a minimum, consider the potential outcomes and transients associated with a failed Surveillance, a successful Surveillance, and a perturbation of the offsite or onsite system when they are tied together or operated independently for the Surveillance; as well as the operator procedures available to cope with these outcomes. These shall be measured against the avoided risk of a plant shutdown and startup to determine that plant safety is maintained or enhanced when the Surveillance is performed in MODE 1 or
: 2. Risk insights or deterministic methods may be used for this assessment.
Credit may be taken for unplanned events that satisfy this SR. Note 2 ensures that the DG is tested under load conditions that are as close to design basis conditions as possible. When synchronized with offsite power, testing should be performed at a power factor of 5 [0.9]. This power factor is representative of the actual inductive loading a DG would see under design basis accident conditions. Under certain conditions, however, Note 2 allows the Surveillance to be conducted at a power factor other than S [0.9]. These conditions occur when grid voltage is high, and the additional field excitation needed to get the power factor to 5 [0.9] results in voltages on the emergency busses that are too high.
Under these conditions, the power factor should be maintained as close as practicable to [0.9] while still maintaining acceptable voltage limits on the emergency busses. In other circumstances, the grid voltage may be such that the DG excitation levels needed to obtain a power factor of
[0.9] may not cause unacceptable voltages on the emergency busses, but the excitation levels are in excess of those recommended for the DG. In such cases, the power factor shall be maintained as close as practicable to
[0.9] without exceeding the DG excitation limits.
WOG STS I3 3.8.1-18 Rev. 3.1, 12/01/05 BASES SURVEILLANCE REQUIREMENTS (continued) sequencing of the largest load.The voltage and frequency specified are consistent with the design range of the equipment powered by the DG.SR 3.8.1.9.a corresponds to the maximum frequency excursion, while SR 3.8.1.9.b and SR 3.8.1.9.c are steady state voltage and frequency values to which the system must recover following load rejection.
Uhe[18 monthJ Frequency is consistent with the recommendation of Regulatory Guide 1.108 (Ref.9)..<:....
This SR is modified by two Notes.The reason for Note 1 is that during operation with the reactor critical, performance of this SR could cause perturbations to the electrical distribution systems that could challenge continued steady state operation and, as a result, unit safety systems.This restriction from normally performing the Surveillance in MODE 1 or 2 is further amplified to allow the Surveillance to be performed for the purpose of reestablishing OPERABILITY (e.g., post work testing following corrective maintenance, corrective modification, deficient or incomplete surveillance testing, and other unanticipated OPERABILITY concerns)provided an assessment determinesplantsafety is maintained or enhanced.This assessment shall, as a minimum, consider the potential outcomes and transients associated with a failed Surveillance, a successful Surveillance, and a perturbation of the offsite or onsite system when they are tied together or operated independently for the Surveillance; as well as the operator procedures available to cope withtheseoutcomes.
These shall be measured against the avoided risk of a plant shutdown and startup to determine that plant safety is maintained or enhanced when the Surveillance is performed in MODE 1 or 2.Risk insights or deterministic methods may be used for this assessment.
Credit may be taken for unplanned events that satisfy this SR.Note 2 ensures that the DG is tested under load conditions that are as close to design basis conditions as possible.When synchronized with offsite power, testing should be performed at a power factor of::;[0.9].This power factor is representative of the actual inductive loading a DG would see under design basis accident conditions.
Under certain conditions, however, Note 2 allows the Surveillance to be conducted at a power factor other than::;[0.9J.These conditions occur when grid voltage is high, and the additional field excitation needed to get the power factor to::;[0.9]results in voltages on the emergency busses that are too high.Under these conditions, the power factor should be maintained as close as practicable to[0.9]while still maintaining acceptable voltage limits on the emergency busses.In other circumstances, the grid voltage may be such that the DG excitation levels needed to obtain a power factor of[0.9]may notcauseunacceptable voltages on the emergency busses, but the excitation levels are in excess of those recommended for the DG.In such cases, the power factor shall be maintained as close as practicable to[0.9]without exceeding the DG excitation limits.WOG STS B 3.8.1-18 Rev.3.1,12/01/05 BASES SURVEILLANCE REQUIREMENTS (continued) REVIEWER'S NOTE
...................................
The above MODE restrictions may be deleted if it can be demonstrated to the staff, on a plant specific basis, that performing the SR with the reactor in any of the restricted MODES can satisfy the following criteria, as applicable:
: a. Performance of the SR will not render any safety system or component inoperable, b. Performance of the SR will not cause perturbations to any of the electrical distribution systems that could result in a challenge to steady state operation or to plant safety systems, and c. Performance of the SR, or failure of the SR, will not cause, or result in, an A00 with attendant challenge to plant safety systems. This Surveillance demonstrates the DG capability to reject a full load without overspeed tripping or exceeding the predetermined voltage limits.
The DG full load rejection may occur because of a system fault or inadvertent breaker tripping.
This Surveillance ensures proper engine generator load response under the simulated test conditions. This test simulates the loss of the total connected load that the DG experiences following a full load rejection and verifies that the DG does not trip upon loss of the load. These acceptance criteria provide for DG damage protection. While the DG is not expected to experience this transient during an event and continues to be available, this response ensures that the DG is not degraded for future application, including reconnection to the bus if the trip initiator can be corrected or isolated.
Fe [I8 month] Frequency is consistent with the recommendation of Regulatory Guide 1 .I08 (Ref. 9) and is intended to be consistent with " -- -._. _ "-,* expected fuel cycle lengths.
4 -.w.,m*, 4nset-W) This SR has been modified by two Notes.
The reason for Note 1 is that during operation with the reactor critical, performance of this SR could cause perturbation to the electrical distribution systems that could challenge continued steady state operation and, as a result, unit safety WOG STS Rev. 3.1, 12/01/05 BASES SURVEILLANCE REQUIREMENTS (continued)
----------------------------------REVI EWE R'S NOTE The above MODE restrictions may be deletedifit can be demonstrated to the staff, on a plant specific basis, that performing the SR with the reactor in any of the restricted MODES can satisfy the following criteria, as applicable:
a.Performance of the SR will not render any safety system or component inoperable, b.Performance of the SR will not cause perturbations to any of the electrical distribution systems that could result in a challenge to steady state operation or toplantsafety systems, and c.Performance of the SR, or failure of the SR, will not cause, or result in, an AOO with attendant challenge to plant safety systems.SR 3.8.1.10 This Surveillance demonstrates the DG capability to reject a full load without overspeed tripping or exceeding the predetermined voltage limits.The DG full load rejection may occur because of a system fault or inadvertent breaker tripping.This Surveillance ensures proper engine generator load response under the simulated test conditions.
This test simulates the loss of the total connected load that the DG experiences following a full load rejection and verifies that the DG does not trip upon loss of the load.These acceptance criteria provide for DG damage protection.
While the DG is not expected to experience this transient during an event and continues to be available, this response ensures that the DG is not degraded for future application, including reconnection to the bus if the trip initiator can be corrected or isolated.U;e[18 month]Frequency is consistent with the recommendation of Regulatory Guide 1.108 (Ref.9)and is intended to be consistent with expected fuel cycle lengths.(-">-..
This SR has been modified by two Notes.The reason for Note 1 is that during operation with the reactor critical, performance of this SR could cause perturbation to the electrical distribution systems that could challenge continued steady state operation and, as a result, unit safety WOGSTS B 3.8.1-19 Rev.3.1,12/01/05 BASES SURVEILLANCE REQUIREMENTS (continued) a I Ehe Frequency of [I8 months] is consistent with the recommendations of .I //I> Regulatory Guide I .I08 (Ref. 9), paragraph 2.a.(l), takes into
: a. I consideration unit conditions required to perform the Surveillance, and is intended to be consistent with expected fuel cycle lengths.
4 ~sW- This SR is modified by two Notes. The reason for Note 1 is to minimize wear and tear on the DGs during testing. For the purpose of this testing, the DGs must be started from standby conditions, that is, with the engine coolant and oil continuously circulated and temperature maintained consistent with manufacturer recommendations. The reason for Note 2 is that performing the Surveillance would remove a required offsite circuit from service, perturb the electrical distribution system, and challenge safety systems.
This restriction from normally performing the Surveillance in MODE I or 2 is further amplified to allow portions of the Surveillance to be performed for the purpose of reestablishing OPERABILITY (e.g., post work testing following corrective maintenance, corrective modification, deficient or incomplete surveillance testing, and other unanticipated OPERABILITY concerns) provided an assessment determines plant safety is maintained or enhanced. This assessment shall, as a minimum, consider the potential outcomes and transients associated with a failed partial Surveillance, a successful partial Surveillance, and a perturbation of the offsite or onsite system when they are tied together or operated independently for the partial Surveillance; as well as the operator procedures available to cope with these outcomes. These shall be measured against the avoided risk of a plant shutdown and startup to determine that plant safety is maintained or enhanced when portions of the Surveillance are performed in MODE I or 2. Risk insights or deterministic methods may be used for the assessment.
Credit may be taken for unplanned events that satisfy this SR. [SR 3.8.1.12 This Surveillance demonstrates that the DG automatically starts and achieves the required voltage and frequency within the specified time
([I 01 seconds) from the design basis actuation signal (LOCA signal) and operates for 2 5 minutes. The 5 minute period provides sufficient time to demonstrate stability.
SR 3.8.1.12.d and SR 3.8.1 "12.e ensure that permanently connected loads and emergency loads are energized from the offsite electrical power system on an ESF signal without loss of offsite power. WOG STS B 3.8.1-22 Rev. 3.1, 12/01/05 BASES SURVEILLANCE REQUIREMENTS (continued)
<: "oft[he Frequency of[18 monthsJ is consistent with the recommendations of I)Regulatory Guide 1.108 (Ref.9), paragraph 2.a.(1), takes into)" If'1, a,/.i consideration unit conditions required to perform the Surveillance, and is intended to be consistent with expected fuel cycle lengths.
This SR is modified by two Notes.The reason for Note 1 is to minimize wear and tear on the DGs during testing.For the purpose of this testing, the DGs must be started from standby conditions, that is, with the engine coolant and oil continuously circulated and temperature maintained consistent with manufacturer recommendations.
The reason for Note 2 is that performing the Surveillance would remove a required offsite circuit from service, perturb the electrical distribution system, and challenge safety systems.This restriction from normally performing the Surveillance in MODE 1 or 2 is further amplified to allow portions of the Surveillance to be performed for the purpose of reestablishing OPERABILITY (e.g., post work testing following corrective maintenance, corrective modification, deficient or incomplete surveillance testing, and other unanticipated OPERABILITY concerns)provided an assessment determines plant safety is maintained or enhanced.This assessment shall, as a minimum, consider the potential outcomes and transients associated with a failed partial Surveillance, a successful partial Surveillance, and a perturbation of the offsite or onsite system when they are tied together or operated independently for the partial Surveillance; as well as the operator procedures available to cope with these outcomes.These shall be measured against the avoided risk of a plant shutdown and startup to determine that plant safety is maintained or enhanced when portions of the Surveillance are performed in MODE 1 or 2.Risk insights or deterministic methods may be used for the assessment.
Credit may be taken for unplanned events that satisfy this SR.[SR 3.8.1.12 This Surveillance demonstrates that the DG automatically starts and achieves the req.uired voltage and frequency within the specified time ([10J seconds)from the design basis actuation signal (LOCA signal)and operates for5 minutes.The 5 minute period provides sufficient time to demonstrate stability.
SR 3.8.1.12.d and SR 3.8.1.12.e ensure that permanently connected loads and emergency loads are energized from the offsite electrical power system on an ESF signal without loss of offsite power.WOGSTS B 3.8.1-22 Rev.3.1,12/01/05 BASES SURVElLLANCE REQUIREMENTS (continued) The requirement to verify the connection of permanent and autoconnected loads is intended to satisfactorily show the relationship of these loads to the DG loading logic. In certain circumstances, many of these loads cannot actually be connected or loaded without undue hardship or potential for undesired operation. For instance, ECCS injection valves are not desired to be stroked open, or high pressure injection systems are not capable of being operated at full flow, or RHR systems performing a decay heat removal function are not desired to be realigned to the ECCS mode of operation.
In lieu of actual demonstration of connection and loading of loads, testing that adequately shows the capability of the DG system to perform these functions is acceptable. This testing may include any series of sequential, overlapping, or total steps so that the entire connection and loading sequence is verified.
Ge Frequency of [18 months] takes into consideration unit conditions required to perform the Surveillance and is intended to be consistent with the expected fuel cycle lengths. Operating experience has shown that these components usually pass the SR when performed at the
[I 8 month] Frequency. Therefore, the Frequency from a reliability standpoint.
4 ... This SR is modified by two Notes. The reason for Note 1 is to minimize wear and tear on the DGs during testing.
For the purpose of this testing, the DGs must be started from standby conditions, that is, with the engine coolant and oil continuously circulated and temperature maintained consistent with manufacturer recommendations. The reason for Note 2 is that during operation with the reactor critical, performance of this Surveillance could cause perturbations to the electrical distribution systems that could challenge continued steady state operation and, as a result, unit safety systems. This restriction from normally performing the Surveillance in MODE 1 or 2 is further amplified to allow portions of the Surveillance to be performed for the purpose of reestablishing OPERABILITY (e.g., post work testing following corrective maintenance, corrective modification, deficient or incomplete surveillance testing, and other unanticipated OPERABILITY concerns) provided an assessment determines plant safety is maintained or enhanced. This assessment shall, as a minimum, consider the potential outcomes and transients associated with a failed partial Surveillance, a successful partial Surveillance, and a perturbation of the offsite or onsite system when they are tied together or operated independently for the partial Surveillance; as well as the operator procedures available to cope with these outcomes. These shall be measured against the avoided risk of a plant shutdown and startup to determine that plant safety is maintained or enhanced when portions of the Surveillance are performed in MODE 1 or 2. Risk insights or deterministic methods may be used for the assessment.
] Credit may be taken for unplanned events that satisfy this SR. WOG STS B 3.8.1-23 Rev. 3.1, 12/01/05 BASES SURVEILLANCE REQUIREMENTS (continued)
The requirement to verify the connection of permanent and autoconnected loads is intended to satisfactorily show the relationship of these loads to the DG loading logic.In certain circumstances, many of these loads cannot actually be connected or loaded without undue hardship or potential for undesired operation.
For instance, EGCS injection valves are not desired to be stroked open, or high pressure injection systems are not capable of being operated at full flow, or RHR systems performing a decay heat removal function are not desired to be realigned to the EGGS mode of operation.
In lieu of actual demonstration of connection and loading of loads, testing that adequately shows the capability of the DG system to perform these functions is acceptable.
This testing may include any series of sequential, overlapping, or total steps so that the entire connection and loading sequence is verified.[;e Frequency of[18 months]takes into consideration unit conditions required to perform the Surveillance and is intended to be consistent with the expected fuel cycle lengths.Operating experience has shown that these components usually pass the SR when performed at the[18 month]Frequency.
Therefore, the Frequency was to be acceptable from a reliability standpoint.
This SR is modified by two Notes.The reason for Note 1 is to minimize wear and tear on the DGs during testing.For the purpose of this testing, the DGs must be started from standby conditions, that is, with the engine coolant and oil continuously circulated and temperature maintained consistent with manufacturer recommendations.
The reason for Note 2 is that during operation with the reactor critical, performance of this Surveillance could cause perturbations to the electrical distribution systems that could challenge continued steady state operation and, as a result, unit safety systems.This restriction from normally performing the Surveillance in MODE 1 or 2 is further amplified to allow portions of the Surveillance to be performed for the purpose of reestablishing OPERABILITY (e.g., post work testing following corrective maintenance, corrective modification, deficient or incomplete surveillancetesting,and other unanticipated OPERABILITY concerns)provided an assessment determines plant safety is maintained or enhanced.This assessment shall, as a minimum, consider the potential outcomes and transients associated with a failed partial Surveillance, a successful partial Surveillance, and a perturbation of the offsite or onsite system when they are tied together or operated independently for the partial Surveillance; as well as the operator procedures available to cope with these outcomes.These shall be measured against the avoided risk of a plant shutdown and startup to determine that plant safety is maintained or enhanced when portions of the Surveillance are performed in MODE 1 or 2.Risk insights or deterministic methods may be used for the assessment.
]Credit may be taken for unplanned events that satisfy this SR.WOGSTS B 3.8.1-23 Rev.3.1,12101/05 BASES SURVEILLANCE REQUIREMENTS (continued) This Surveillance demonstrates that DG noncritical protective functions (e.g., high jacket water temperature) are bypassed on a loss of voltage signal concurrent with an ESF actuation test signal. Noncritical automatic trips are all automatic trips except:
: a. Engine overspeed;
: b. Generator differential current;
[c. Low lube oil pressure;
: d. High crankcase pressure; and e. Start failure relay.] The noncritical trips are bypassed during DBAs and provide an alarm on an abnormal engine condition. This alarm provides the operator with sufficient time to react appropriately.
The DG availability to mitigate the DBA is more critical than protecting the engine against minor problems that are not immediately detrimental to emergency operation of the DG. Ehe 118 month] Frequency is based on engineering judgment, taking into consideration unit conditions required to perform the Surveillance, and is intended to be consistent with expected fuel cycle lengths. Operating experience has shown that these components usually pass the SR when oehormed at the 118 month1 ~reauencv. Therefore, the Freauencv was
'concluded to be ~cceptablifrom'a relkbility standpoint.
f -g;-f'Tij The SR is modified by a Note. The reason for the Note is that performing the Surveillance would remove a required DG from service. This restriction from normally performing the Surveillance in MODE I or 2 is further amplified to allow the Surveillance to be performed for the purpose of reestablishing OPERABILITY (e.g., post work testing following corrective maintenance, corrective modification, deficient or incomplete surveillance testing, and other unanticipated OPERABILITY concerns) provided an assessment determines plant safety is maintained or enhanced. This assessment shall, as a minimum, consider the potential outcomes and transients associated with a failed Surveillance, a successful Surveillance, and a perturbation of the offsite or onsite system when they are tied together or operated independently for the Surveillance; as well as the operator procedures available to cope with these outcomes. These shall be measured against the avoided risk of a plant shutdown and startup to determine that plant safety is maintained or enhanced when the Surveillance is performed in MODE 1 or 2. Risk - WOG STS -- Rev. 3.1, 12/01/05 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.8.1.13 This Surveillance demonstrates that DG noncritical protective functions (e.g., high jacket water temperature) are bypassed on a loss of voltage signal concurrent with an ESF actuation test signal.Noncritical automatic trips are all automatic trips except: a.Engine overspeed; b.Generator differential current;[c.Low lube oil pressure;d.High crankcase pressure;and e.Start failure relay.]The noncritical trips are bypassed during DBAs and provide an alarm on an abnormal engine condition.
This alarm provides the operator with sufficient time to react appropriately.
The DG availability to mitigate the DBA is more critical than protecting the engine against minor problems that are notimmediatelydetrimental to emergency operation of the DG.frhe[18 month]Frequency is based on engineering judgment, taking into consideration unit conditions required to perform the Surveillance, and is intended to be consistent with expected fuel cycle lengths.Operating experience has shown that these components usually pass the SR when performed at the[18 month]Frequency.
Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.
The SR is modified by a Note.The reason for the Note is that performing the Surveillance would remove a required DG from service.This restriction from normally performing the Surveillance in MODE 1 or 2 is further amplified to allow the Surveillance to be performed for the purpose of reestablishing OPERABILITY (e.g., post work testing following corrective maintenance, corrective modification, deficient or incomplete surveillance testing, and other unanticipated OPERABILITY concerns)provided an assessment determines plant safety is maintained or enhanced.This assessment shall, as a minimum, consider the potential outcomes and transients associated with a failed Surveillance, a successful Surveillance, and a perturbation of the offsite or on site system when they are tied together or operated independently for the Surveillance; as well as the operator procedures available to cope with these outcomes.These shall be measured against the avoided risk of a plant shutdown and startup to determine that plant safety is maintained or enhanced when the Surveillance is performed in MODE 1 or 2.Risk WOGSTS B 3.8.1-24 Rev.3.1,12/01/05 BASES SURVEILLANCE REQUIREMENTS (continued) insights or deterministic methods may be used for this assessment.
Credit may be taken for unplanned events that satisfy this SR. ...................................
REVIEWER'S NOTE .............................
-----.. The above MODE restrictions may be deleted if it can be demonstrated to the staff, on a plant specific basis, that performing the SR with the reactor in any of the restricted MODES can satisfy the following criteria, as applicable:
: a. Performance of the SR will not render any safety system or component inoperable, b. Performance of the SR will not cause perturbations to any of the electrical distribution systems that could result in a challenge to steady state operation or to plant safety systems, and Regulatory Guide 1.108 (Ref.
9), paragraph Z.a.(3), requires demonstration~nc~
18mnth$that the DGs can start and run continuously at full load capability for an interval of not less than 24 hours, 2 [Z] hours of which is at a load equivalent to 110% of the continuous duty rating and the remainder of the time at a load equivalent to the continuous duty rating of the DG. The DG starts for this Surveillance can be performed either from standby or hot conditions. The provisions for prelubricating and warmup, discussed in SR 3.8.1.2, and for gradual loading, discussed in SR 3.8.1.3, are applicable to this SR.
The load band is provided to avoid routine overloading of the DG. Routine overloading may result in more frequent teardown inspections in accordance with vendor recommendations in order to maintain DG OPERABILITY.
Ehhe [18 month] Frequency is consistent with the recommendations of Regulatory Guide 1.108 (Ref. 9), paragraph 2.a.(3), takes into consideration unit conditions required to perform the Surveillance, and is intended to be consistent with expected fuel cycle lengths. +-L@GQ This Surveillance is modified by three Notes. Note 1 states that momentary transients due to changing bus loads do not invalidate this test. Similarly, momentary power factor transients above the power factor WOG STS B 3.8.1-25 Rev. 3.1, 12/01/05 BASES SURVEILLANCE REQUIREMENTS (continued) insights or deterministic methods may be used for this assessment.
Credit may be taken for unplanned events that satisfy this SR.-----------------------------------REV I EWE R'S NOTE The above MODE restrictions may be deletedifit can be demonstrated to the staff, on a plant specific basis, that performing the SR with the reactor in any of the restricted MODES can satisfy the following criteria, as applicable:
a.Performance of the SR will not render any safety system or component inoperable, b.Performance of the SR will not cause perturbations to any of the electrical distribution systems that could result in a challenge to steady state operation or to plant safety systems, and c.Performance of the SR, or failure of the SR, will not cause, or result in, an AOO with attendant challenge to plant safety systems.SR 3.8.1.14 Regulatory Guide 1.108 Ref.9, aragraph 2.a.(3), requires demonstration one 18 nth that the DGs can start and run continuously at full load capability for an interval of not less than 24 hours,[2]hours of which is at a load equivalent to 110%of the continuous duty rating and the remainder of the time at a load equivalent to the continuous duty rating of the DG.The DG starts for this Surveillance can be performed either from standby or hot conditions.
The provisions for prelubricating and warmup, discussed in SR 3.8.1.2, and for gradual loading, discussed in SR 3.8.1.3, are applicable to this SR.The load band is provided to avoid routine overloading of the DG.Routine overloading may result in more frequent teardown inspections in accordance with vendor recommendations in order to maintain DG OPERABILITY.
[fhe[18 month]Frequency is consistent with the recommendations of Regulatory Guide 1.108 (Ref.9), paragraph 2.a.(3), takes into consideration unit conditions required to perform the Surveillance, and is intended to be consistent with expected fuel cycle lengths.
This Surveillance is modified by three Notes.Note 1 states that momentary transients due to changing bus loads do not invalidate this test.Similarly, momentary power factor transients above the power factor WOGSTS B 3.8.1-25 Rev.3.1,12/01/05 BASES SURVEILLANCE REQUIREMENTS (continued)
Ehe [I8 month] Frequency is consistent with the recommendations of Regulatory Guide 1.108 (Ref. 9), paragraph 2.a.(5). t-, This SR is modified by two Notes. Note 1 ensures that the test is performed with the diesel sufficiently hot. The load band is provided to avoid routine overloading of the DG. Routine overloads may resuk in more frequent teardown inspections in accordance with vendor recommendations in order to maintain DG OPERABILITY. The requirement that the diesel has operated for at least [2] hours at full load conditions prior to performance of this Surveillance is based on manufacturer recommendations for achieving hot conditions. Momentary transients due to changing bus loads do not invalidate this test. Note 2 allows all DO starts to be preceded by an engine prelube period to minimize wear and tear on the diesel during testing.
As required by Regulatory Guide 1 .I08 (Ref. 9), paragraph 2.a.(6), this Surveillance ensures that the manual synchronization and automatic load transfer from the DG to the offsite source can be made and the DG can be returned to ready to load status when offsite power is restored.
It also ensures that the autostart logic is reset to allow the DG to reload if a subsequent loss of offsite power occurs. The DG is considered to be in ready to load status when the DG is at rated speed and voltage, the output breaker is open and can receive an autoclose signal on bus undervoltage, and the load sequence timers are reset.
6e Frequency of (18 months] is consistent with the recommendations of Regulatory Guide 1 .I08 (Ref. 9), paragraph 2.a.(6), and takes into consideration unit conditions required to perform the Surveillance.
This SR is modified by a Note. The reason for the Note is that performing the Surveillance would remove a required offsite circuit from service, perturb the electrical distribution system, and challenge safety systems. This restriction from normally performing the Surveillance in MODE 1 or 2 is further amplified to allow the Surveillance to be performed for the purpose of reestablishing OPERABILITY (e.g., post work testing following corrective maintenance, corrective modification, deficient or incomplete surveillance testing, and other unanticipated OPERABILITY concerns) provided an assessment determines plant safety is maintained or enhanced. This assessment shall, as a minimum, consider the potential outcomes and transients associated with a failed Surveillance, a successful Surveillance, and a perturbation of the offsite or onsite system when they are tied together or operated independently for the Surveillance; as well as the operator procedures available to cope with WOG STS B 3.8.1-27 Rev. 3.1, 12101105 BASES SURVEILLANCE REQUIREMENTS (continued)
G'he[18 month]Frequency is consistent with the recommendations of Regulatory Guide 1,108 (Ref.9), paragraph 2.a,(5), (--.4r):2e c[2)This SR is modified by two Notes.Note 1 ensures that the test is performed with the diesel sufficiently hot.The load band is proVided to avoid routine overloading of the DG, Routine overloads may result in more frequent teardown inspections in accordance with vendor recommendations in order to maintain DG OPERABILITY, The requirement that the diesel has operated for at least[2]hours at full load conditions prior to performance of this Surveillance is based on manufacturer recommendations for achieving hot conditions.
Momentary transients due to changing bus loads do not invalidate this test.Note 2 allows all DG starts to be preceded by an engine prelube period to minimize wear and tear on the diesel during testing.SR 3.8,1.16 As required by Regulatory Guide 1.108 (Ref.9), paragraph 2,a.(6), this Surveillance ensures that the manual synchronization and automatic load transfer from the DG to the offsite source can be made and the DG can be returned to ready to load status when offsite power is restored.It also ensures that the autostart logic is reset to allow the DG to reload if a subsequent loss of offsite power occurs.The DG is considered to be in ready to load status when the DG is at rated speed and voltage, the output breaker is open and can receive an autoclose signal on bus undervoltage, and the load sequence timers are reset.[he Frequency of[18 months]is consistent with the recommendations of Regulatory Guide 1.108 (Ref.9), paragraph 2.a.(6), and takes into_consideration unit conditions required to perform the Surveillance,<: m:....h-S-e,.-y@
This SR is modified by a Note, The reason for the Note is that performing the Surveillance would remove a required offsite circuit from service, perturb the electrical distribution system, and challenge safety systems, This restriction from normally performing the Surveillance in MODE 1 or 2 is further amplified to allow the Surveillance to be performed for the purpose of reestablishing OPERABILITY (e,g., post work testing following corrective maintenance, corrective modification, deficient or incomplete surveillance testing, and other unanticipated OPERABILITY concerns)provided an assessment determines plant safety is maintained or enhanced.This assessment shall, as a minimum, consider the potential outcomes and transients associated with a failed Surveillance, a successful Surveillance, and a perturbation of the offsite or onsite system when they are tied together or operated independently for the Surveillance; as well as the operator procedures available to with WOG STS B 3,8,1-27 Rev.3.1,12/01/05 BASES SURVEILLANCE REQUIREMENTS (continued) these outcomes. These shall be measured against the avoided risk of a plant shutdown and startup to determine that plant safety is maintained or enhanced when the Surveillance is performed in MODE 1 or 2. Risk insights or deterministic methods may be used for this assessment.
Credit may be taken for unplanned events that satisfy this SR. [SR 3.8.1.17 Demonstration of the test mode override ensures that the DG availability under accident conditions will not be compromised as the result of testing and the DG will automatically reset to ready to load operation if a LOCA actuation signal is received during operation in the test mode. Ready to load operation is defined as the DG running at rated speed and voltage with the DG output breaker open. These provisions for automatic switchover are required by IEEE-308 (Ref.
13), paragraph 6.2.6(2).
The requirement to automatically energize the emergency loads with offsite power is essentially identical to that of SR 3.8.1.12. The intent in the requirement associated with SR 3.8.1.17.b is to show that the emergency loading was not affected by the DG operation in test mode. In lieu of actual demonstration of connection and loading of loads, testing that adequately shows the capability of the emergency loads to perform these functions is acceptable. This testing may include any series of sequential, overlapping, or total steps so that the entire connection and loading sequence is verified.
Ehe [I8 month] Frequency is consistent with the recommendations of Regulatory Guide 1.108 (Ref. 9), paragraph 2.a.(8), takes into consideration unit conditions required to perform the Surveillance, and is intended to be consistent with expected fuel cycle lengths.
$-/;-'"'''TT pu- r/ This SR is modified by a Note. The reason for the Note is that performing the Surveillance would remove a required offsite circuit from service, perturb the electrical distribution system, and challenge safety systems. This restriction from normally performing the Surveillance in MODE 1 or 2 is further amplified to allow portions of the Surveillance to be performed for the purpose of reestablishing OPERABILITY (e.g., post work testing following corrective maintenance, corrective modification, deficient or incomplete surveillance testing, and other unanticipated OPERABILITY concerns) provided an assessment determines plant safety is maintained or enhanced. This assessment shall, as a minimum, consider the potential outcomes and transients associated with a failed partial Surveillance, a successful partial Surveillance, and a perturbation of the offsite or onsite system when they are tied together or operated WOG STS 8 3.8.1-28 Rev. 3.1, 12/01/05 BASES SURVEILLANCE REQUIREMENTS (continued)theseoutcomes.
These shall be measured against the avoided risk of a plant shutdown and startup to determine that plant safety is maintained or enhanced when the Surveillance is performed in MODE 1 or 2.Risk insights or deterministic methods may be used for this assessment.
Credit may be for unplanned events that satisfy this SR.[SR 3.8.1.17 Demonstration of the test mode override ensures that the DG availability under accident conditions will not be compromised as the result of testing and the DG will automatically reset to ready to load operation if a LOCA actuation signal is received during operation in the test mode.Ready to load operation is defined as the DG running at rated speed and voltage with the DG output breaker open.These provisions for automatic switchover are required by IEEE-308 (Ref.13), paragraph 6.2.6(2).The requirement to automatically energize the emergency loads with offsite power is essentially identical to that of SR 3.8.1.12.The intent in the requirement associated with SR 3.8.1.17.b is to show that the emergency loading was not affected by the DG operation in test mode.In lieu of actual demonstration of connection and loading of loads, testing that adequately shows the capability of the emergency loads to perform these functions is acceptable.
This testing may include any series of sequential, overlapping, or total steps so that the entire connection and loading sequence is verified.[fhe[18 month]Frequency is consistent with the recommendations of Regulatory Guide 1.108 (Ref.9), paragraph 2.a.(8), takes into consideration unit conditions required to perform the Surveillance, and is intended to be consistent with expected fuel cycle lengths.
This SR is modified by a Note.The reason for the Note is that performing the Surveillance would remove a required offsite circuit from service, perturb the electrical distribution system, and challenge safety systems.This restriction from normally performing the Surveillance in MODE 1 or 2 is further amplified to allow portions of the Surveillance to be performed for the purpose of reestablishing OPERABILITY (e.g., post work testing following corrective maintenance, corrective modification, deficient or incomplete surveillance testing, and other unanticipated OPERABILITY concerns)provided an assessment determines plant safety is maintained or enhanced.This assessment shall, as a minimum, consider the potential outcomes and transients associated with a failed partial Surveillance, a successful partial Surveillance, and a perturbation of the offsite or onsite system when they are tied together or operated WOGSTS B 3.8.1-28 Rev.3.1, 12/01/05 BASES SURVEILLANCE REQUIREMENTS (continued) independently for the partial Surveillance; as well as the operator procedures available to cope with these outcomes. These shall be measured against the avoided risk of a plant shutdown and startup to determine that plant safety is maintained or enhanced when portions of the Surveillance are performed in MODE 1 or 2. Risk insights or deterministic methods may be used for the assessment.
] Credit may be taken for unplanned events that satisfy this SR. Under accident [and loss of offsite power] conditions loads are sequentially connected to the bus by the [automatic load sequencer].
The sequencing logic controls the permissive and starting signals to motor breakers to prevent overloading of the DGs due to high motor starting currents. The
[lo]% load sequence time interval tolerance ensures that sufficient time exists for the DG to restore frequency and voltage prior to applying the next load and that safety analysis assumptions regarding ESF equipment time delays are not violated. Reference 2 provides a summary of the automatic loading of ESF buses.
@e Frequency of Regulatory Guide consideration unit
[I8 months] is consistent with the recommendations of 1 .I08 (Ref. 9), paragraph 2.a.(2), takes into conditions reauired to ~erform the Surveillance, and is intended to be consistent with expected fuel cycle lengths.
+q5zzrm This SR is modified by a Note. The reason for the Note is that performing the Surveillance would remove a required offsite circuit from service, perturb the electrical distribution system, and challenge safety systems.
This restriction from normally performing the Surveillance in MODE I or 2 is further amplified to allow the Surveillance to be performed for the purpose of reestablishing OPERABILITY (e.g., post work testing following corrective maintenance, corrective modification, deficient or incomplete surveillance testing, and other unanticipated OPERABILITY concerns) provided an assessment determines plant safety is maintained or enhanced. This assessment shall, as a minimum, consider the potential outcomes and transients associated with a failed Surveillance, a successful Surveillance, and a perturbation of the offsite or onsite system when they are tied together or operated independently for the Surveillance; as well as the operator procedures available to cope with these outcomes. These shall be measured against the avoided risk of a plant shutdown and startup to determine that plant safety is maintained or enhanced when the Surveillance is performed in MODE 1 or 2. Risk insights or deterministic methods may be used for this assessment.
Credit may be taken for unplanned events that satisfy this SR. WOG STS B 3.8.1-29 Rev. 3.1. 12101105 BASES SURVEILLANCE REQUIREMENTS (continued) independently for the partial Surveillance; as well as the operator procedures available to cope withtheseoutcomes.
These shall be measured against the avoided risk of a plant shutdown and startup to determine thatplantsafety is maintained or enhanced when portions of the Surveillance are performed in MODE 1 or 2.Risk insights or deterministic methods may be used for the assessment.]
Credit may be taken for unplanned events that satisfy this SR.SR 3.8.1.18 Under accident[and loss of offsite power]conditions loads are sequentially connected to the bus by the[automatic load sequencer].
The sequencing logic controls the permissive and starting signals to motor breakers to prevent overloading of the DGs due to high motor starting currents.The[10]%load sequence time interval tolerance ensures that sufficient time exists for the DG to restore frequency and voltage prior to applying the next load and that safety analysis assumptions regarding ESF equipment time delays are not violated.Reference 2 provides a summary of the automatic loading of ESF buses.[;e Frequency of[18 months]is consistent with the recommendations of Regulatory Guide 1.108 (Ref.9), paragraph 2.a.(2), takes into consideration unit conditions required to perform the Surveillance, and is intended to be consistent with expected fuel cycle lengths.
This SR is modified by a Note.The reason for the Note is that performing the Surveillance would remove a required offsite circuit from service, perturb the electrical distribution system, and challenge safety systems.This restriction from normally performing the Surveillance in MODE 1 or 2 is further amplified to allow the Surveillance to be performed for the purpose of reestablishing OPERABILITY (e.g., post work testing following corrective maintenance, corrective modification, deficient or incomplete surveillance testing, and other unanticipated OPERABILITY concerns)provided an assessment determines plant safety is maintained or enhanced.This assessment shall, as a minimum, consider the potential outcomes and transients associated with a failed Surveillance, a successful Surveillance, and a perturbation of the offsite or onsite system when they are tied together or operated independently for the Surveillance; as well as the operator procedures available to cope with these outcomes.These shall be measured against the avoided risk of a plant shutdown and startup to determine thatplantsafety is maintained or enhanced when the Surveillance is performed in MODE 1 or 2.Risk insights or deterministic methods may be used for this assessment.
Credit may be taken for unplanned events that satisfy this SR.WOGSTS B 3.8.1-29 Rev.3.1,12/01/05 BASES SURVEILLANCE REQUIREMENTS (continued)
...................................
REVIEWER'S NOTE ................................... The above MODE restrictions may be deleted if it can be demonstrated to the staff, on a plant specific basis, that performing the SR with the reactor in any of the restricted MODES can satisfy the following criteria, as applicable:
: a. Performance of the SR will not render any safety system or component inoperable, b. Performance of the SR will not cause perturbations to any of the electrical distribution systems that could result in a challenge to steady state operation or to plant safety systems, and In the event of a DBA coincident with a loss of offsite power, the DGs are required to supply the necessary power to *SF systems so that the fuel, RCS, and containment design limits are not exceeded.
This Surveillance demonstrates the DG operation, as discussed in the Bases for SR 3.8.1 .I 1, during a loss of offsite power actuation test signal in conjunction with an ESF actuation signal. In lieu of actual demonstration of connection and loading of loads, testing that adequately shows the capability of the DG system to perform these functions is acceptable. This testing may include any series of sequential, overlapping, or total steps so that the entire connection and loading sequence is verified.
Ehe Frequency of
[I8 months] takes into consideration unit conditions required to perform the Surveillance and is intended to be consisisttwith an expected fuel cycle length of
[I8 months]. < -++@&y-ta This SR is modified by two Notes. The reason for Note 1 is to minimize wear and tear on the DGs during testing.
For the purpose of this testing, the DGs must be started from standby conditions, that is, with the engine coolant and oil continuously circulated and temperature maintained consistent with manufacturer recommendations for DGs. The reason for Note 2 is that the performance of the Surveillance would remove a required offsite circuit from service, perturb the electrical distribution system, and challenge safety systems. This restriction from normally WOG STS -- B 3.8.1-30 Rev. 3.1, 12/01/05 BASES SURVEILLANCE REQUIREMENTS (continued)
EVI EWE R'S NOTE-----------------------------------
The above MODE restrictions may be deleted if it can be demonstrated to the staff, on a plant specific basis, that performing the SR with the reactor in any of the restricted MODES can satisfy the following criteria, as applicable:
a.Performance of the SR will not render any safety system or component inoperable, b.Performance of the SR will not cause perturbations to any of the electrical distribution systems that could result in a challenge to steady state operation or to plant safety systems, and c.Performance of the SR, or failure of the SR, will not cause, or result in, an AOO with attendant challenge to plant safety systems.SR 3.8.1.19 In the event of a DBA coincident with a loss of offsite power, the DGs are required to supply the necessary power to ESF systems so that the fuel, RCS, and containment design limits are not exceeded.This Surveillance demonstrates the DG operation, as discussed in the Bases for SR 3.8.1.11, during a loss of offsite power actuation test signal in conjunction with an ESF actuation signal.In lieu of actual demonstration of connection and loading of loads, testing that adequately shows the capability of the DG system to perform these functions is acceptable.
This testing may include any series of sequential, overlapping, or total steps so that the entire connection and loading sequence is verified.[[he Frequency of[18 months]takes into consideration unit conditions required to perform the Surveillance and is intended to be consistent with an expected fuel cycle length of[18 months].
This SR is modified by two Notes.The reason for Note 1 is to minimize wear and tear on the DGs during testing.For the purpose of this testing, the DGs must be started from standby conditions, that is, with the engine coolant and oil continuously circulated and temperature maintained consistent with manufacturer recommendations for DGs.The reason for Note 2 is that the performance of the Surveillance would remove a required offsite circuit from service, perturb the electrical distribution system, and challenge safety systems.This restriction from normally WOGSTS B 3.8.1-30 Rev.3.1,12/01/05 BASES SURVEILLANCE REQUIREMENTS (continued) performing the Surveillance in MODE I or 2 is further amplified to allow portions of the Surveillance to be performed for the purpose of reestablishing OPERABILITY (e.g., post work testing following corrective maintenance, corrective modification, deficient or incomplete surveillance testing, and other unanticipated OPERABILITY concerns) provided an assessment determines plant safety is maintained or enhanced.
This assessment shall, as a minimum, consider the potential outcomes and transients associated with a failed partial Surveillance, a successful partial Surveillance, and a perturbation of the offsite or onsite system when they are tied together or operated independently for the partial Surveillance; as well as the operator procedures available to cope with these outcomes. These shall be measured against the avoided risk of a plant shutdown and startup to determine that plant safety is maintained or enhanced when portions of the Surveillance are performed in MODE 1 or 2. Risk insights or deterministic methods may be used for the assessment. Credit may be taken for unplanned events that satisfy this SR. This Surveillance demonstrates that the DG starting independence has not been compromised. Also, this Surveillance demonstrates that each engine can achieve proper speed within the specified time when the DGs are started simultaneously.
fie 10 vear Freauencv is consistent with the recommendations of L ----- ~e~ula<ory
~uidi I .lo8 (Ref. 9). <<&... t-] This SR is modified by a Note. The reason for the Note is to minimize wear on the DG during testing.
For the purpose of this testing, the DGs must be started from standby conditions, that is, with the engine coolant and oil continuously circulated and temperature maintained consistent with manufacturer recommendations.
WOG STS B 3.8.1-31 Rev. 3.1, 12/01/05 BASES SURVEILLANCE REQUIREMENTS (continued) performing the Surveillance in MODE 1 or 2 is further amplified to allow portions of the Surveillance to be performed for the purpose of reestablishing OPERABILITY (e.g., post work testing following corrective maintenance, corrective modification, deficient or incomplete surveillance testing, and other unanticipated OPERABILITY concerns)provided an assessment determines plant safety is maintained or enhanced.This assessment shall, as a minimum, consider the potential outcomes and transients associated with a failed partial Surveillance, a successful partial Surveillance, and a perturbation of the offsite or onsite system when they are tied together or operated independently for the partial Surveillance; as well as the operator procedures available to cope with these outcomes.These shall be measured against the avoided risk of a plant shutdown and startup to determine that plant safety is maintained or enhanced when portions of the Surveillance are performed in MODE 1 or 2.Risk insights or deterministic methods may be used for the assessment.
Credit may be taken for unplanned events that satisfy this SR.SR 3.8.1.20 This Surveillance demonstrates that the DG starting independence has not been compromised.
Also, this Surveillance demonstrates that each engine can achieve proper speed within the specified time when the DGs are started simultaneously.
[he 10 year Frequency is consistent with the recommendations of RegUlatory Guide 1.108 (Ref.
This SR is modified by a Note.The reason for the Note is to minimize wear on the DG during testing.For the purpose of this testing, the DGs must be started from standby conditions, that is, with the engine coolant and oil continuously circulated and temperature maintained consistent with manufacturer recommendations.
WOGSTS B Rev.3.1, 12/01/05 Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 BASES ACTIONS (continued) With a Required Action and associated Completion Time not met, or one or more DG's fuel oil, lube oil, or starting air subsystem not within limits for reasons other than addressed by Conditions A through D, the associated DG may be incapable of performing its intended function and must be immediately declared inoperable.
SURVEILLANCE SR 3.8.3.1 REQUIREMENTS This SR provides verification that there is an adequate inventory of fuel oil in the storage tanks to support each DG's operation for 7 days at full load. The 7 day period is sufficient time to place the unit in a safe shutdown condition and to bring in replenishment fuel from an offsite location.
The 31 day Frequency is adequate to ensure that a sufficient supply of uel oil is available, since low level alarms are provided and unit operators L would be aware of any large uses of fuel oil during this period.
Qn~ert'l)
SR 3.8.3.2 This Surveillance ensures that sufficient lube oil inventory is available to support at least 7 days of full load operation for each DG. The [500] gal requirement is based on the DG manufacturer consumption values for the run time of the DG. Implicit in this SR is the requirement to verify the capability to transfer the lube oil from its storage location to the DG, when the DG lube oil sump does not hold adequate inventory for 7 days of full load operation without the level reaching the manufacturer recommended minimum level.
31 day Frequency is adequate to ensure that a sufficient lube oil supply is onsite, since DG starts and run time are closely monitored by the unit The tests listed below are a means of determining whether new fuel oil is of the appropriate grade and has not been contaminated with substances that would have an immediate, detrimental impact on diesel engine combustion. If results from these tests are within acceptable limits, the fuel oil may be added to the storage tanks without concern for WOG STS B 3.8.3-5 Rev. 3.0, 03/31/04 Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 BASES ACTIONS (continued)
With a Required Action and associated Completion Time not met, or one or more DG's fuel oil, lube oil, or starting air subsystem not within limits for reasons other than addressed by Conditions A through D, the associated DG may be incapable of performing its intended function and must be immediately declared inoperable.
SURVEILLANCE REQUIREMENTS SR 3.8.3.1 This SR provides verification that there is an adequate inventory of fuel oil in the storage tanks to support each DG's operation for 7 days at full load.The 7 day period is sufficient time to place the unit in a safe shutdown condition and to bring in replenishment fuel from an offsite location.rThe 31 day Frequency is adequate to ensure that a sufficient supply of oil is available, since low level alarms are provided and unit operators would be aware of any large uses of fuel oil during this period.J:nserJ?)SR 3.8.3.2 This Surveillance ensures that sufficient lube oil inventory is available to support at least 7 days of full load operation for each DG.The[500]gal requirement is based on the DG manufacturer consumption values for the run time of the DG.Implicit in this SR is the requirement to verify the capability to transfer the lube oil from its storage location to the DG, when the DG lube oil sump does not hold adequate inventory for 7 days of full load operation without the level reaching the manufacturer recommended minimum level.Q\31 day Frequency is adequate to ensure that a sufficient lube oil supply is onsite, since DG starts and run time are closely monitored by the unit staff.
...
SR 3.8.3.3 The tests listed below are a means of determining whether new fuel oil is of the appropriate grade and has not been contaminated with substances that would have an immediate, detrimental impact on diesel engine combustion.
If results from these tests are within acceptable limits, the fuel oil may be added to the storage tanks without concern for WOG STS B 3.8.3-5 Rev.3.0, 03/31104 Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 BASES SURVEILLANCE REQUIREMENTS (continued) Particulate concentrations should be determined in accordance with ASTM D5452-[ ] (Ref. 6). This method involves a gravimetric determination of total particulate concentration in the fuel oil and has a limit of 10 mgll. It is acceptable to obtain a field sample for subsequent laboratory testing in lieu of field testing. [For those designs in which the total stored fuel oil volume is contained in two or more interconnected tanks, each tank must be considered and tested separately.] - The Frequency of this test takes into consideration fuel oil degradation trends that indicate that particulate concentration is unlikely to change significantly between Frequency intervals. This Surveillance ensures that, without the aid of the refill compressor, sufficient air start capacity for each DG is available.
The system design requirements provide for a minimum of [five] engine start cycles without recharging.
[A start cycle is defined by the DG vendor, but usually is measured in terms of time (seconds of cranking) or engine cranking speed.] The pressure specified in this SR is intended to reflect the lowest value at which the [five] starts can be accomplished.
Ee 31 day Frequency takes into account the capacity, capability, redundancy, and diversity of the AC sources and other indications available in the control room, including alarms, to alert the operator to below normal air start pressure.
6.. ---.m-,w-!u*w$ Microbiological fouling is a major cause of fuel oil degradation. There are numerous bacteria that can grow in fuel oil and cause fouling, but all must have a water environmen~~~der to survive. Removal of water from the fuel storage tanks@S&kry
~;3aaelirninates the necessary environment for bacterial survival.
This is the most effective means of controlling microbiological fouling. In addition, it eliminates the potential for water entrainment in the fuel oil during DG operation.
Water may WOG STS B 3.8.3-7 Rev. 3.0, 03/31/04 Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 BASES SURVEILLANCE REQUIREMENTS (continued)
Particulate concentrations should be determined in accordance with ASTM D5452-[](Ref.6).This method involves a gravimetric determination of total particulate concentration in the fuel oil and has a limit of 10 mgt!.It is acceptable to obtain a field sample for subsequent laboratory testing in lieu of field testing.[For those designs in which the total stored fuel oil volume is contained in two or more interconnected tanks, each tank must be considered and tested separately.]
-The Frequency of this test takes into consideration fuel oil degradation trends that indicate that particulate concentration is unlikely to change significantly between Frequency intervals.
SR 3.8.3.4 This Surveillance ensures that, without the aid of the refill compressor, sufficient air start capacity for each DG is available.
The system design requirements provide for a minimum of[five]engine start cycles without recharging.
[A start cycle is defined by the DG vendor, but usually is measured in terms of time (seconds of cranking)or engine cranking speed.]The pressure specified in this SR is intended to reflect the lowest value at which the[five)starts can be accomplished.
frhe 31 day Frequency takes into account the capacity, capability, redundancy, and diversity of the AC sources and other indications available in the control room, including alarms, to alert the operator to below normal air start pressure.("""" a_.-"I n5ert.2 SR 3.8.3.5 Microbiological fouling is a major cause of fuel oil degradation.
There are numerous bacteria that can grow in fuel oil and cause fouling, but all must have a water environment in order to survive.Removal of water from the fuel storage the necessary environment for bacterial survival.This is the most effective means of controlling microbiological fouling.In addition, it eliminates the potential for water entrainment in the fuel oil during DG operation.
Water may WOGSTS B 3.8.3-7 Rev.3.0, 03/31/04 Diesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 BASES SURVEILLANCE REQUIREMENTS (continued) come from any of several sources, including condensation, ground water, rain water, and contaminated fuel oil, and from breakdown of the fuel oil by bacteria.
Frequent checking for and removal of accumulated water minimizes fouling and provides data regarding the watertight integrity of J REFERENCES
: 1. FSAR, Section E9.5.4.21.
: 2. Regulatory Guide 1 .I 37. 3. ANSI N195-1976, Appendix B. 4. FSAR, Chapter [6]. 5. FSAR, Chapter [I 51. 6. ASTM Standards:
04057-[ 1; D975-[ 1; D1298-[ 1; D4176-[ 1; [D2709-[ I;] 01552-[ 1; D2622-[ 1; D4294-[ 1; D5452-[ 1. 7. ASTM Standards, D975-[ 1, Table I. WOG STS Rev. 3.0, 03/31/04 Oiesel Fuel Oil, Lube Oil, and Starting Air B 3.8.3 BASES SURVEILLANCE REQUIREMENTS (continued) come from any of several sources, including condensation, ground water, rain water, and contaminated fuel oil, and from breakdown of the fuel oil by bacteria.Frequent checking for and removal of accumulated water minimizes fouling and provides data regardingthewatertight integrity of the fuel oil system.The Surveillance Frequencies are established by Regulatory Guide 1.137 (Ref.2).This SR is for maintenance.
The presence of water does not necessarily represent failure of this SR, provided the accumulated water is removed during performance
___Surveillance.
-_***__
0 REFERENCES 1.FSAR, Section[9.5.4.2].
2.Regulatory Guide 1.137.3.ANSI N195-1976, Appendix B.4.FSAR, Chapter[6).5.FSAR, Chapter[15}.6.ASTM Standards:
04057-[];0975-[};
];04176-[];[02709-[];]
];02622-[];04294-[];05452-[].7.ASTM Standards, 0975-[], Table 1.WOGSTS B 3.8.3-8 Rev.3.0, 03/31/04 DC Sources - Operating B 3.8.4 BASES SURVEILLANCE SR 3.8.4.d REQUIREMENTS Verifying battery terminal voltage while on float charge helps to ensure the effectiveness of the battery chargers, which support the ability of the batteries to perform their intended function. Float charge is the condition in which the charger is supplying the continuous charge required to overcome the internal losses of a battery and maintain the battery in a fully charged state while supplying the continuous steady state loads of the associated DC subsystem. On float charge, battery cells will receive adequate current to optimally charge the battery.
The voltage requirements are based on the nominal design voltage of the battery and are consistent with the minimum float voltage established by the battery manufacturer (12.201 Vpc or [127.6] V at the battery terminals). This voltage maintains the battery plates in a condition that supports maintaining the grid life (expected to be approximately 20 years).fihhe 7 day Frequency is consistent with manufacturer recommendations and IEEE-450 (Ref. 8). 4 .-,.,. e-;;g= This SR verifies the design capacity of the battery chargers. According to Regulatory Guide 1.32 (Ref. 9), the battery charger supply is recommended to be based on the largest combined demands of the various steady state loads and the charging capacity to restore the battery from the design minimum charge state to the fully charged state, irrespective of the status of the unit during these demand occurrences. The minimum required amperes and duration ensure that these requirements can be satisfied.
This SR provides two options. One option requires that each battery charger be capable of supplying
[400] amps at the minimum established float voltage for [8] hours. The ampere requirements are based on the output rating of the chargers.
The voltage requirements are based on the charger voltage level after a response to a loss of AC power. The time period is sufficient for the charger temperature to have stabilized and to have been maintained for at least [2] hours. The other option requires that each battery charger be capable of recharging the battery after a service test coincident with supplying the largest coincident demands of the various continuous steady state loads (irrespective of the status of the plant during which these demands occur). This level of loading may not normally be available following the WOG STS B 3.8.4-8 Rev. 3.0, 03131104 BASES SURVEILLANCE REQUIREMENTS DC Sources-Operating B 3.8.4 SR 3.8.4.1 Verifying battery terminal voltage while on float charge helps to ensure the effectiveness of the battery chargers, which support the ability of the batteries to perform their intended function.Float charge is the condition in which the charger is supplying the continuous charge required to overcome the internal losses of a battery and maintain the battery in a fully charged state while supplying the continuous steady state loads oftheassociated DC subsystem.
On float charge, battery cells will receive adequate current to optimally charge the battery.The voltage requirements are based on the nominal design voltage of the battery and are consistent with the minimum float voltage established by the battery manufacturer
([2.20]Vpc or[127.6]V at the battery terminals).
This voltage maintains the battery plates in a condition that supports maintaining the grid life (expected to be approximately 20 years).Uhe 7 day Frequency is consistent with manufacturer recommendations and IEEE-450 (Ref.8).
--
SR 3.8.4.2 This SR verifies thedesigncapacity of the battery chargers.According to RegUlatory Guide 1.32 (Ref.9), the battery charger supply is recommended to be based on the largest combined demands of the various steady state loads and the charging capacity to restore the battery from the design minimum charge state to the fully charged state, irrespective of the status of the unit during these demand occurrences.
The minimum required amperes and duration ensure that these requirements can be satisfied.
This SR provides two options.One option requires that each battery charger be capable of supplying[400]amps at the minimum established float voltage for[8]hours.The ampere requirements are based on the output rating of the chargers.The voltage requirements are based on the charger voltage level after a response to a loss of AC power.The time period is sufficient for the charger temperature to have stabilized and to have been maintained for at least[2]hours.The other option requires that each battery charger be capable of recharging the battery after a service test coincident with supplying the largest coincident demands of the various continuous steady state loads (irrespective of the status of the plant during which these demands occur).This level of loading may not normally be available following the WOGSTS B 3.8.4-8 Rev.3.0, 03/31/04 DC Sources - Operating B 3.8.4 BASES SURVEILLANCE REQUIREMENTS (continued) battery service test and will need to be supplemented with additional loads. The duration for this test may be longer than the charger sizing criteria since the battery recharge is affected by float voltage, temperature, and the exponential decay in charging current. The battery is recharged when the measured charging current is 5 [2] amps. [She Surveillance Frequency is acceptable, given the unit conditions required to perform the test and the other administrative controls existing to ensure adequate charger performance during these
[I8 month] intervals.
In addition, this Frequency is intended to be consistent with expected fuel cycle lengths. E=J A battery service test is a special test of the battery capability, as found, to satisfy the design requirements (battery duty cycle) of the DC electrical power system. The discharge rate and test length should correspond to the design duty cycle requirements as specified in Reference
: 4. @e Surveillance Frequency of (18 months] is consistent with the recommendations of Regulatory Guide 1.32 (Ref. 9) and Regulatory Guide 1.129 (Ref. lo), which state that the battery service test should be performed during refueling operations, or at some other outage, with intervals between tests not to exceed
[I8 months]. +.,* ---+(=i7&XQ This SR is modified by two Notes. Note I allows the performance of a modified performance discharge test in lieu of a service test.
The reason for Note 2 is that performing the Surveillance would perturb the electrical distribution system and challenge safety systems. This restriction from normally performing the Surveillance in MODE 1 or 2 is further amplified to allow portions of the Surveillance to be performed for the purpose of reestablishing OPERABILITY (e.g., post work testing following corrective maintenance, corrective modification, deficient or incomplete surveillance testing, and other unanticipated OPERABILITY concerns) provided an assessment determines plant safety is maintained or enhanced. This assessment shall, as a minimum, consider the potential outcomes and transients associated with a failed partial WOG STS B 3.8.4-9 Rev. 3.0, 03/31/04 DC Sources-Operating B 3.8.4 BASES SURVEILLANCE REQUIREMENTS (continued) battery service test and will need to be supplemented with additional loads.The duration for this test may be longer than the charger sizing criteria since the battery recharge is affected by float voltage, temperature, and the exponential decay in charging current.The battery is recharged when the measured charging current is:s;[2J amps.Uhe Surveillance Frequency isacceptable,given the unit conditions required to perform the test and the other administrative controls existing to ensure adequate charger performance during these[18 monthJ intervals.
In addition, this Frequency is intended to be consistent with expected fuel cycle
,._SR 3.8.4.3 A battery service test is a special test of the battery capability, as found, to satisfy the design requirements (battery duty cycle)of the DC electrical power system.The discharge rate and test length should correspond to the design duty cycle requirements as specified in Reference 4.&sect;e Surveillance Frequency of[18 monthsJ is consistent with the recommendations of Regulatory Guide 1.32 (Ref.9)and Regulatory Guide 1.129 (Ref.10), which state that the battery service test should be performed during refueling operations, or at some other outage, with intervals between tests not to exceed[18 monthsJ.
This SR is modified by two Notes.Note 1 allows the performance of a modified performance discharge test in lieu of a service test.The reason for Note 2 is that performing the Surveillance would perturb the electrical distribution system and challenge safety systems.This restriction from normally performing the Surveillance in MODE 1 or 2 is further amplified to allow portions of the Surveillance to be performed for the purpose of reestablishing OPERABILITY (e.g., post work testing following corrective maintenance, corrective modification, deficient or incomplete surveillance testing, and other unanticipated OPERABILITY concerns)provided an assessment determines plant safety is maintained or enhanced.This assessment shall, as a minimum, consider the potential outcomes and transients associated with a failed partial WOGSTS B 3.8.4-9 Rev.3.0, 03/31/04 Battery Parameters B 3.8.6 BASES SURVEILLANCE SR 3.8.6.1 REQUIREMENTS Verifying battery float current while on float charge is used to determine the state of charge of the battery.
Float charge is the condition in which the charger is supplying the continuous charge required to overcome the internal losses of a battery and maintain the battery in a charged state.
The float current requirements are based on the float current indicative of a charged battery. Use of float current to determi e the state of charge of the battery is consistent with IEEE-450 (Ref. l).$he 7 day Frequency is consistent with IEEE-450 (Ref. 1). -5ZKf--ic-i This SR is modified by a Note that states the float current requirement is not required to be met when battery terminal voltage is less than the minimum established float voltage of SR 3.8.4.1. When this float voltage is not maintained the Required Actions of LC0 3.8.4 ACTION A are being taken, which provide the necessary and appropriate verifications of the battery condition. Furthermore, the float current limit of [2] amps is established based on the nominal float voltage value and is not directly applicable when this voltage is not maintained.
SR 3.8.6.2 and SR 3.8.6.5 Optimal long term battery performance is obtained by maintaining a float voltage greater than or equal to the minimum established design limits provided by the battery manufacturer, which corresponds to [I 30.51 V at the battery terminals, or
[2.25] Vpc. This provides adequate over- potential, which limits the formation of lead sulfate and self discharge, which could eventually render the battery inoperable. Float voltages in this range or less, but greater than
[2.07] Vpc, are addressed in Specification 5.5.17. SRs 3.8.6.2 and 3.8.6.5 require verification that the cell float voltages are equal to or greater than the short term absolute minimum voltage of [2.07] V. Ehe Frequency for cell voltage verification every 31 days for pilot cell and32 days for each connected cell is consistent with IEEE-450 (Ref. 1). The limit specified for electrolyte level ensures that the plates suffer no hysical damage and maintains adequate electron transfer capability. consistent with IEEE-450 (Ref. 1). P WOE STS B 3.8.6-6 Rev. 3.0, 03/31/04 BASES SURVEILLANCE REQUIREMENTS Battery Parameters B 3.8.6 SR 3.8.6.1 Verifying battery float current while on float charge is used to determine the state of charge of the battery.Float charge is the condition in which the charger is supplying the continuous charge required to overcome the internal losses of a battery and maintain the battery in a charged state.The float current requirements are based on the float current indicative of a charged battery.Use of float current to the state of charge of the battery is consistent with IEEE-450(Ref.1).l..!-he 7 day Frequency is consistent with IEEE-450 (Ref.1).
..':L.nser"l.&
--,.."......__.-This SR is modified by a Note that states the float current requirement is not required to be met when battery terminal voltage is less than the minimum established float voltage of SR 3.8.4.1.When this float voltage is not maintained the Required Actions of LCO 3.8.4 ACTION A are being taken, which provide the necessary and appropriate verifications of the battery condition.
Furthermore, the float current limit of[2]amps is established based on the nominal float voltage value and is not directly applicable when this voltage is not maintained.
SR 3.8.6.2 and SR 3.8.6.5 Optimal long term battery performance is obtained by maintaining a float voltage greater than or equal to the minimum established design limits provided by the battery manufacturer, which corresponds to[130.5]V at the battery terminals, or[2.25]Vpc.This provides adequatepotential, which limits the formation of lead sulfate and self discharge, which could eventually render the battery inoperable.
Float voltages in this range or less, but greater than[2.07]Vpc, are addressed in Specification 5.5.17.SRs 3.8.6.2 and 3.8.6.5 require verification that the cell float voltages are equal to or greater than the short term absolute minimum voltage of[2.07]V.[he Frequency for cell voltage verification every 31 days for pilot cell and 92 days for each connected cell is consistent with IEEE-450 (Ref.1).
SR 3.8.6.3 The limit specified for electrolyte levelensuresthat the plates suffer no-physical damage and maintains adequate electron transfer capability.
L The Frequency is censistent with IEEE-450 (Ref.1).(OJ 3 Cda-W WOGSTS B 3.8.6-6 Rev.3.0, 03/31/04 Battery Parameters B 3.8.6 BASES SURVEILLANCE REQUIREMENTS (continued) This Surveillance verifies that the pilot cell temperature is greater than or equal to the minimum established design limit (i.e., [40IoF). Pilot cell electrolyte temperature is maintained above this temperature to assure the battery can provide the required current and voltage to meet the design requirements. Temperatures lower than calculations act to inhibit or reduce battery capacity. consistent with IEEE-450 (Ref. 1). SR 3.8.6.6 A battery performance discharge test is a test of constant current capacity of a battery, normally done in the as found condition, after having been in service, to detect any change in the capacity determined by the acceptance test. The test is intended to determine overall battery degradation due to age and usage. Either the battery performance discharge test or the modified performance discharge test is acceptable for satisfying SR 3.8.6.6; however, only the modified performance discharge test may be used to satisfy the battery service test requirements of SR 3.8.4.3. A modified discharge test is a test of the battery capacity and its ability to provide a high rate, short duration load (usually the highest rate of the duty cycle).
his will often confirm the battery's ability to meet the critical period of the load duty cycle, in addition to determining its percentage of rated capacity. Initial conditions for the modified performance discharge test should be identical to those specified for a service test. It may consist of just two rates; for instance the one minute rate for the battery or the largest current load of the duty cycle, followed by the test rate employed for the performance test, both of which envelope the duty cycle of the service test. Since the ampere-hours removed by a one minute discharge represents a very small portion of the battery capacity, the test rate can be changed to that for the performance test without compromising the results of the performance discharge test. The battery terminal voltage for the modified performance discharge test must remain above the minimum battery terminal voltage specified in the battery service test for the duration of time equal to that of the service test.
WOG STS B 3.8.6-7 Rev. 3.0, 03/31/04 Battery Parameters B 3.8.6 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.8.6.4 This Surveillance verifies that the pilot cell temperature is greater than or equal to the minimum established design limit (i.e.,[40]OF).Pilot cell electrolyte temperature is maintained above this temperature to assure the battery can provide the required current and voltage to meet the design requirements.
Temperatures lower than assumed in battery sizing calculations act to inhibit or reduce battery capacity.(Jhe consistent with IEEE-450 (Ref.__,...of-31 do-5SR 3.8.6.6 A battery performance discharge test is a test of constantcurrentcapacity of a battery, normally done in the as found condition, after having been in service, to detect any change in the capacity determined by the acceptance test.The test is intended to determine overall battery degradation due toageand usage.Either the battery performance discharge test or the modified performance discharge test is acceptable for satisfying SR 3.8.6.6;however, only the modified performance discharge test may be used to satisfy the battery service test requirements of SR 3.8.4.3.A modified discharge test is a test of the battery capacity and its ability to provide a high rate, short duration load (usually the highest rate of the duty cycle).This will often confirm the battery's ability to meet the critical period of the load duty cycle, in addition to determining its percentage of rated capacity.Initial conditions for the modified performance discharge test should be identical tothosespecified for a service test.It may consist of just two rates;for instance the one minute rate for the battery or the largest current load of the duty cycle, followed by the test rate employed for the performance test, both of which envelope the duty cycle of the service test.Since the ampere-hours removed by a one minute discharge represents a very small portion of the battery capacity, the test rate can be changed to that for the performance test without compromising the results of the performance discharge test.The battery terminal voltage for the modified performance discharge test must remain above the minimum battery terminal voltage specified in the battery service test for the duration of time equal to that of the service test.WOGSTS B 3.8.6-7 Rev.3.0, 03/31/04 Battery Parameters B 3.8.6 BASES SURVEILLANCE REQUIREMENTS (continued)
The acceptance criteria for this Surveillance are consistent with IEEE-450 (Ref.1)and IEEE-485 (Ref.5).These references recommend that the battery be replaced if its capacity is below 80%of the manufacturer's rating.A capacity of 80%shows that the battery rate of deterioration'is increasing, even if there is ample capacity to meet the load requirements.
Furthermore, the battery is sized to meet the assumed duty cycle loads when the battery design capacity reaches this[80]%limit.
[Jhe Surveillance Frequency for this test is normally 60 months.If the battery shows degradation, or if the battery has reached 85%of its expected life and capacity is<100%ofthemanufacturer's rating, the Surveillance Frequency is reduced to 12 months.However, if the battery shows no degradation but has reached 85%of its expected life, the Surveillance Frequency is only reduced to 24 months for batteries that retain capacity100%of the manufacturer's ratings.Degradation is indicated, according to IEEE-450 (Ref.1), when the battery capacity drops by more than 10%relative to its capacity on the previous performance test or when it is[10%]below the manufacturer's rating.These Frequencies are consistent with the recommendations in IEEE-450 (Ref.1).This SR is modified by a Note.The reason for the Note is that performing the Surveillance would perturb the electrical distribution system and challenge safety systems.This restriction from normally performing the Surveillance in MODE 1 or 2 is further amplified to allow portions of the Surveillance to be performed for the purpose of reestablishing OPERABILITY (e.g., post work testing following corrective maintenance, corrective modification, deficient or incomplete surveillance testing, and other unanticipated OPERABILITY concerns)provided an assessment determines plant safety is maintained or enhanced.This assessment shall, as a minimum, consider the potential outcomes and transients associated with a failed partial Surveillance, a successful partial Surveillance, and a perturbation of the offsite or onsite system when they are tied together or operated independently for the partial Surveillance; as well as the operator procedures available to cope with these outcomes.These shall be measured against the avoided risk of a plant shutdown and startup to determine that plant safety is maintained or enhanced when portions of the Surveillance are performed in MODE 1 or 2.Risk insights or deterministic methods may be used for the assessment.
Credit may be taken for unplanned events that satisfy this SR.WOG STS B 3.8.6-8 Rev.3.0, 03/31/04 Battery Parameters B 3.8.6 BASES SURVEILLANCE REQUIREMENTS (continued)
The acceptance criteria for this Surveillance are consistent with IEEE-450 (Ref.1)and IEEE-485 (Ref.5).These references recommend that the battery be replaced if its capacity is below 80%of the manufacturer's rating.A capacity of 80%shows that the battery rate of deterioration'is increasing, even if there is ample capacity to meet the load requirements.
Furthermore, the battery is sized to meet the assumed duty cycle loads when the battery design capacity reaches this[80]%limit.
[Jhe Surveillance Frequency for this test is normally 60 months.If the battery shows degradation, or if the battery has reached 85%of its expected life and capacity is<100%ofthemanufacturer's rating, the Surveillance Frequency is reduced to 12 months.However, if the battery shows no degradation but has reached 85%of its expected life, the Surveillance Frequency is only reduced to 24 months for batteries that retain capacity100%of the manufacturer's ratings.Degradation is indicated, according to IEEE-450 (Ref.1), when the battery capacity drops by more than 10%relative to its capacity on the previous performance test or when it is[10%]below the manufacturer's rating.These Frequencies are consistent with the recommendations in IEEE-450 (Ref.1).This SR is modified by a Note.The reason for the Note is that performing the Surveillance would perturb the electrical distribution system and challenge safety systems.This restriction from normally performing the Surveillance in MODE 1 or 2 is further amplified to allow portions of the Surveillance to be performed for the purpose of reestablishing OPERABILITY (e.g., post work testing following corrective maintenance, corrective modification, deficient or incomplete surveillance testing, and other unanticipated OPERABILITY concerns)provided an assessment determines plant safety is maintained or enhanced.This assessment shall, as a minimum, consider the potential outcomes and transients associated with a failed partial Surveillance, a successful partial Surveillance, and a perturbation of the offsite or onsite system when they are tied together or operated independently for the partial Surveillance; as well as the operator procedures available to cope with these outcomes.These shall be measured against the avoided risk of a plant shutdown and startup to determine that plant safety is maintained or enhanced when portions of the Surveillance are performed in MODE 1 or 2.Risk insights or deterministic methods may be used for the assessment.
Credit may be taken for unplanned events that satisfy this SR.WOG STS B 3.8.6-8 Rev.3.0, 03/31/04 Inverters - Operating B 3.8.7 BASES SURVEILLANCE SR 3.8.7.1 REQUIREMENTS This Surveillance verifies that the inverters are functioning properly with all required circuit breakers closed and AC vital buses energized from the inverter. The verification of proper voltage and frequency output ensures that the required power is readily available for the instrumentation of the RPS and ESFAS connected to the AC vital buses. ghe 7 day Frequency takes into account the redundant capability of the inverters and other indications available in the control room that alert the operator to inverter -.."-h.".
."" malfunctions.
C-"-'"C-T REFERENCES
: 1. FSAR, Chapter [8]. 2. FSAR, Chapter [6]. 3. FSAR, Chapter [15]. WOG STS Rev. 3.0, 03/31/04 Inverters-Operating B 3.8.7 BASES SURVEILLANCE SR 3.8.7.1 REQUIREMENTS This Surveillance verifies that the inverters are functioning properly with all required circuit breakers closed and AC vital buses energized from the inverter.The verification of proper voltage and frequency output ensures that the required power is readily available for the of the RPS and ESFAS connected to the AC vital buses.\lhe 7 day Frequency takes into account the redundant capability of the inverters and other indications available in the control room that alert the operator to" inverter malfunctions.
REFERENCES 1.FSAR, Chapter[8].2.FSAR, Chapter[6].3.FSAR, Chapter[15].WOGSTS B 3.8.7-4 Rev.3.0, 03/31/04 Inverters - Shutdown B 3.8.8 BASES ACTIONS (continued) additions) that could result in loss of required SDM (MODE
: 5) or boron concentration (MODE 6). Suspending positive reactivity additions that could result in failure to meet the minimum SDM or boron concentration limit is required to assure continued safe operation. Introduction of coolant inventory must be from sources that have a boron concentration greater than that what would be required in the RCS for minimum SDM or refueling boron concentration.
This may result in an overall reduction in RCS boron concentration, but provides acceptable margin to maintaining subcritical operation. lntroduction of temperature changes including temperature increases when operating with a positive MTC must also be evaluated to ensure they do not result in a loss of required SDM. Suspension of these activities shall not preclude completion of actions to establish a safe conservative condition. These actions minimize the probability of the occurrence of postulated events. It is further required to immediately initiate action to restore the required inverter[s]
and to continue this action until restoration is accomplished in order to provide the necessary inverter power to the unit safety systems. The Completion Time of immediately is consistent with the required times for actions requiring prompt attention.
The restoration of the required inverters should be completed as quickly as possible in order to minimize the time the unit safety systems may be without power or powered from a constant voltage source transformer.
SURVEILLANCE SR 3.8.8.1 REQUIREMENTS This Surveillance verifies that the inverters are functioning properly with all required circuit breakers closed and AC vital buses energized from the inverter.
The verification of proper voltage and frequency output ensures that the required power is readily available for the instrumentation connected to the AC vital buses.
Ehe 7 day Frequency takes into account the redundant capability of the inverters and other indications available in the control room that alert the operator to inverter malfunctions.
el--..., REFERENCES
: 1. FSAR, Chapter 161. (T_~~sL'~~
9 2. FSAR, Chapter 1151. WOG STS Rev. 3.0, 03131104 Inverters-Shutdown B 3.8.8 BASES ACTIONS (continued) additions) that could result in loss of required SDM (MODE 5)or boron concentration (MODE 6).Suspending positive reactivity additions that could result in failure to meet the minimum SDM or boron concentration limit is required to assure continued safe operation.
Introduction of coolant inventory must be from sources that have a boron concentration greater than that what would be required in the RCS for minimum SDM or refueling boron concentration.
This may result in an overall reduction in RCS boron concentration, but provides acceptable margin to maintaining subcritical operation.
Introduction of temperature changes including temperature increases when operating with a positive MTC must also be evaluated to ensure they do not result in a loss of required SDM.Suspension of these activities shall not preclude completion of actions to establish a safe conservative condition.
These actions minimize the probability of the occurrence of postulated events.It is further required to immediatelyinitiateaction to restore the required inverter[s]
and to continue this action until restoration is accomplished in order to provide the necessary inverter power to the unit safety systems.The Completion Time of immediately is consistent with the required times for actions requiring prompt attention.
The restoration of the required inverters should be completed as quickly as possible in order to minimize the time the unit safety systems may be without power or powered from a constant voltage source transformer.
SURVEILLANCE REQUIREMENTS REFERENCES SR 3.8.8.1 This Surveillance verifies that the inverters are functioning properly with all required circuit breakers closed and AC vital buses energized from the inverter.The verification of proper voltage and frequency output ensures that the required power is readily available for the instrumentation connected to the AC vital buses.[Ihe 7 day Frequency takes into account the redundant capability of the inverters and other indications available in the control room that alert the operator to inverter malfunctions.
{_."".*1.FSAR, Chapter[6].
Y'" t r 2.FSAR, Chapter[15].WOGSTS B 3.8.8-4 Rev.3.0, 03/31/04 Distribution Systems - Operating 6 3.8.9 BASES ACTIONS (continued)
Condition E corresponds to a level of degradation in the electrical power distribution system that causes a required safety function to be lost. When more than one inoperable electrical power distribution subsystem results in the loss of a required function, the plant is in a condition outside the accident analysis. Therefore, no additional time is justified for continued operation.
LC0 3.0.3 must be entered immediately to commence a controlled shutdown.
SURVEILLANCE SR 3.8.9.1 REQUIREMENTS This Surveillance verifies that the [required]
AC, DC, and AC vital bus electrical power distribution systems are functioning properly, with the correct circuit breaker alignment. The correct breaker alignment ensures the appropriate separation and independence of the electrical divisions is maintained, and the appropriate voltage is available to each required bus. The verification of proper voltage availability on the buses ensures that the required voltage is readily available for motive as well as functions for critical system loads connected to these buses.
f! The ntrol 7 day Frequency takes into account the redundant capability of the AC, DC, and AC vital bus electrical power distribution subsystems, and other indications available in the control room that alert the operator to subsystem malfunctions.
+.. , .-.-In I-.. REFERENCES
: 1. FSAR, Chapter
[6]. /&set4 k,,, ..,* _..- 2) -- 2. FSAR, Chapter [I 51. 3. Regulatory Guide 1.93, December 1974. WOG STS Rev. 3.1, 12/01/05 Distribution Systems-Operating B 3.8.9 BASES ACTIONS (continued)
Condition E corresponds to a level of degradation in the electrical power distribution system that causes a required safety function to be lost.When more than one inoperable electrical power distribution subsystem results in the loss of a required function, the plant is in a condition outside the accident analysis.Therefore, no additional time is justified for continued operation.
LCO 3.0.3 must be entered immediately to commence a controlled shutdown.SURVEILLANCE REQUIREMENTS SR 3.8.9.1 FSAR, Chapter[6].1.This Surveillance verifies that the[required]
AC, DC, and AC vital bus electrical power distribution systems are functioning properly, with the correct circuit breaker alignment.
The correct breaker alignment ensures the appropriate separation and independence of the electrical divisions is maintained, and the appropriate voltage is available to each required bus.The verification of proper voltage availability on the buses ensures that the required voltage is readily available for motive as well as functions for critical system loads connected to these buses.LIhe 7 day Frequency takes into account the redundant capability of the AC, DC, and AC vital bus electrical power distribution SUbsystems, and other indications available in the control room that alert the operator to subsystem malfunctions.
{-....,..",.REFERENCES 2.FSAR, Chapter[15].3.Regulatory Guide 1.93, December 1974.WOGSTS B 3.8.9-7 Rev.3.1, 12/01/05 Distribution Systems - Shutdown B 3.8.10 BASES ACTIONS (continued) The Completion Time of immediately is consistent with the required times for actions requiring prompt attention.
The restoration of the required distribution subsystems should be completed as quickly as possible in order to minimize the time the unit safety systems may be without power. SURVEILLANCE SR 3.8.10.1 REQUIREMENTS This Surveillance verifies that the AC, DC, and AC vital bus electrical power distribution subsystems are functioning properly, with all the buses energized. The verification of proper voltage availability on the buses ensures that the required power is readily available for motive as well as control functions for critical system loads connected to these buses.
ahe 7 day Frequency takes into account the capability of the electrical power distribution subsystems, and other indications available in the control room that alert the operator to subsystem malfunctions.
v REFERENCES
: 1. FSAR, Chapter
[6]. O~nser t~) 2. FSAR, Chapter 11 51. WOG STS Rev. 3.0, 03/31/04 Distribution Systems-Shutdown B 3.8.10 BASES ACTIONS (continued)
The Completion Time of immediately is consistent with the required times for actions requiring prompt attention.
The restoration of the required distribution subsystems should be completed as quickly as possible in order to minimize the time the unit safety systems may be without power.SURVEILLANCE SR 3.8.10.1 REQUIREMENTS This Surveillance verifies that the AC, DC, and AC vital bus electrical power distribution subsystems are functioning properly, with all the buses energized.
The verification of proper voltage availability on the buses ensures that the required power is readily available for motive as well as control functions for critical system loads connected to these buses.(fhe 7 day Frequency takes into account the capability of the electrical power distribution subsystems, and other indications available in the control room that alert the operator to subsystem malfunctions
...(;""'''REFERENCES 1.FSAR, Chapter[6J.Xn S e" 2.FSAR.Chapter[15].WOG STS B 3.8.10-4 Rev.3.0, 03/31/04 Boron Concentration B 3.9.1 BASES SURVEILLANCE SR 3.9.1 .I REQUIREMENTS This SR ensures that the coolant boron concentration in the RCS, and connected portions of the refueling canal and the refueling cavity, is within the COLR limits. The boron concentration of the coolant in each required volume is determined periodically by chemical analysis. Prior to re- connecting portions of the refueling canal or the refueling cavity to the RCS, this SR must be met per SR 3.0.4. If any dilution activity has occurred while the cavity or canal were disconnected from the RCS, this SR ensures the correct boron concentration prior to communication with the RCS. SA minimum Frequency of once every 72 hours is a reasonable amount of time to verify the boron concentration of representative samples.
The Frequency is based on operating experience, which has shown 72 hours to be adequate.
4 - - %m--dh REFERENCES
: 1. 10 CFR 50, Appendix A, GDC 26. 2. FSAR, Chapter
[I 51. WOG STS Rev. 3.0, 03/31/04 BASES SURVEILLANCE REQUIREMENTS REFERENCES Boron Concentration B 3.9.1 SR 3.9.1.1 This SR ensures that the coolant boron concentration in the RCS, and connected portions of the refueling canal and the refueling cavity, is within the COLR limits.The boron concentration of the coolant in each required volume is determined periodically by chemical analysis.Prior toconnecting portions of the refueling canal or the refueling cavity to the RCS, this SR must be met per SR 3.0.4.If any dilution activity has occurred while the cavity or canal were disconnected from the RCS, this SR ensures the correct boron concentration prior to communication with the RCS.[A minimum Frequency of once every 72 hours is a reasonable amount of time to verify the boron concentration of representative samples.The Frequency is base...d on ope.
has shown 72 hours to be adequate.k,->o.,,".__
1.10 CFR 50, Appendix A, GDC 26.2.FSAR, Chapter[15J.WOGSTS B Rev.3.0, 03/31/04
[Unborated Water Source Isolation Valves] B 3.9.2 BASES SURVEILLANCE SR 3.9.2.1 REQUIREMENTS These valves are to be secured closed to isolate possible dilution paths. The likelihood of a significant reduction in the boron concentration during MODE 6 operations is remote due to the large mass of borated water in the refueling cavity and the fact that all unborated water sources are isolated, precluding a dilution. The boron concentration is checked every 72 hours during MODE 6 under SR 3.9.1.1. This Surveillance demonstrates that the valves are closed through a system walkdown.
Ehe 31 day Frequency is based on engineering judgment and is considered reasonable in view of other administrative controls that will ensure that the valve opening is an unlikely possibility.
+ REFERENCES I FSAR, Section [15.2.4].
: 2. NUREG-0800, Section 15.4.6. WOG STS Rev. 3.0, 03/31/04 BASES SURVEILLANCE REQUIREMENTS
[Un borated Water Source Isolation Valves]B 3.9.2 SR 3.9.2.1 These valves are to be secured closed to isolate possible dilution paths.The likelihood of a significant reduction in the boron concentration during MODE 6 operations is remote due to the large mass of borated water in the refueling cavity and the fact that all unborated watersourcesare isolated, precluding a dilution.The boron concentration is checked every 72 hours during MODE 6 under SR 3.9.1.1.This Surveillance demonstrates that the valves are closed through a system walkdown.(lhe 31 day Frequency is based on engineering judgment and is considered reasonable in view of other administrative controls that will ensure that the valve opening is an unlikely possibility.
REFERENCES WOGSTS 1.FSAR, Section[15.2.4].2.NUREG-0800, Section 15.4.6.B 3.9.2-3 Rev.3.0, 03/31/04 Nuclear Instrumentation B 3.9.3 BASES SURVEILLANCE SR 3.9.3.1 REQUIREMENTS SR 3.9.3.1 is the performance of a CHANNEL CHECK, which is a comparison of the parameter indicated on one channel to a similar parameter on other channels.
It is based on the assumption that the two indication channels should be consistent with core conditions. Changes in fuel loading and core geometry can result in significant differences between source range channels, but each channel should be consistent with its local conditions.
Fe Frequency of 12 hours is consistent with the CHANNEL CHECK Frequency specified similarly for the same instruments in LC0 3.3.1. SR 3.9.3.2 SR 3.9.3.2 is the performance of a CHANNEL CALIBRATIO$~)
@&xfiF$ This SR is modified by a Note stating that neutron detectors are =ded from the CHANNEL CALIBRATION.
The CHANNEL CALIBRATION for the source range neutron flux monitors consists of obtaining the detector plateau or preamp discriminator curves, evaluating those curves, and comparing the curves to the manufacturer's data. Vhe CHANNEL CALIBRATION also includes verification of the audible [alarm] [count rate] function.]
rhe 18 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage. Operating experience has shown these components usually
-. pass-the Surveillance when performed at the 18 month Frequencv.
r REFERENCES 1.
10 CFR 50, Appendix A, GDC 13, GDC 26, GDC 28, and GDC 29. 2. FSAR, Section 115.2.41.
WOG STS Rev. 3.0, 03/31/04 Nuclear Instrumentation B 3.9.3 BASES SURVEILLANCE SR 3.9.3.1 REQUIREMENTS SR 3.9.3.1 is the performance of a CHANNEL CHECK, which is a comparison of the parameter indicated on one channel to a similar parameter on other channels.It is based on the assumption that the two indication channels should be consistent with core conditions.
Changes in fuel loading and core geometry can result in significant differences between source range channels, but each channel should be consistent with its local conditions.
{Efte Frequency of 12 hours is consistent with the CHANNEL CHECK Frequency specified similarly for the same instruments in LCO 3.3.1.-_._--........'\
tZ)REFERENCES SR 3.9.3.2 SR 3.9.3.2 is the performance of a CHANNELThis SR is modified by a Note stating that neutron detectors areexauded from the CHANNEL CALIBRATION.
The CHANNEL CALIBRATION for the source range neutron flux monitors consists of obtaining the detector plateau or preamp discriminator curves, evaluating those curves, and comparing the curves to the manufacturer's data.[The CHANNEL CALIBRATION also includes verification of the audible[alarm}[count rate}function.}
[he 18 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage.Operating experience has shown these components usually pass the Surveillance when performed at the 18 month Frequency.1.10 CFR 50, Appendix A, GDC 13, GDC 26, GDC 28, and GDC 29. 2.FSAR, Section[15.2.4}.WOGSTS B 3.9.3-4 Rev.3.0, 03/31/04 Containment Penetrations B 3.9.4 BASES ACTIONS A.1 If the containment equipment hatch, air locks, or any containment penetration that provides direct access from the containment atmosphere to the outside atmosphere is not in the required status, including the Containment Purge and Exhaust Isolation System not capable of automatic actuation when the purge and exhaust valves are open, the unit must be placed in a condition where the isolation function is not needed. This is accomplished by immediately suspending movement of [recently] irradiated fuel assemblies within containment. Performance of these actions shall not preclude completion of movement of a component to a safe position. SURVEILLANCE SR 3.9.4.1 REQUIREMENTS This Surveillance demonstrates that each of the containment penetrations required to be in its closed position is in that position. The Surveillance on the open purge and exhaust valves will demonstrate that the valves are not blocked from closing. Also the Surveillance will demonstrate that each valve operator has motive power, which will ensure that each valve is capable of being closed by an OPERABLE automatic containment purge and exhaust isolation signal. r~he Surveillance is performed every 7 days during movement of [recently]
irradiated fuel assemblies within containment.
The Surveillance interval is selected to be commensurate with the normal duration of time to complete fuel handling operations.
A surveillance before the start of refueling operations will provide two or three surveillance verifications during the applicable period for this LCO.
As such, this Surveillance ensures that a postulated fuel handling accident [involving handling recently irradiated fuel] that releases fission product radioactivity within the containment will not result in a release of significant fission product radioactivity to the environment in excess of those recommended by Standard Review Plan Section 15.7.4 (Reference 3). This Surveillance demonstrates that each containment purge and exhaust valve actuates to its isolation position on manual initiation or on an actual or simulated high radiation signal.che 18 month Frequency maintains consistency with other similar ESFAS instrumentation and valve testing requirements.
In LC0 3.3.6, the Containment Purge and Exhaust WOG STS B 3.9.4-6 Rev. 3.0, 03/31/04 BASES ACTIONS SURVEILLANCE REQUIREMENTS Containment Penetrations B 3.9.4 If the containment equipment hatch, air locks, or any containment penetration that provides direct access from the containment atmosphere to the outside atmosphere is not in therequiredstatus, including the Containment Purge and Exhaust Isolation System not capable of automatic actuation when the purge and exhaust valves are open, the unit must be placed in a condition where the isolation function is not needed.This is accomplished by immediately suspending movement of[recently]
irradiated fuel assemblies within containment.
Performance of these actions shall not preclude completion of movement of a component to a safe position.SR 3.9.4.1 This Surveillance demonstrates that each of the containment penetrations required to be in its closed position is in that position.The Surveillance on the open purge and exhaust valves will demonstrate that the valves are not blocked from closing.Also the Surveillance will demonstrate that each valve operator has motive power, which will ensure that each valve is capable of being closed by an OPERABLE automatic containment purge and exhaust isolation signal.[The Surveillance is performed every 7 days during movement of[recently]
irradiated fuel assemblies within containment.
The Surveillance interval is selected to be commensurate with the normal duration of time to complete fuel handling operations.
A surveillance before the start of refueling operations will provide two or three surveillance verifications during the applicable period for this LCO.As such, this Surveillance ensures that a postulated fuel handling accident[involving handling recently irradiated fuel]that releases fission product radioactivity within the containment will not result in a release of significant fission product radioactivity to the environment in excess of those recommended by Standard Review Plan Section 15.7.4 (ReferenceV\se.,.+-V SR 3.9.4.2 This Surveillance demonstrates that each containment purge and exhaust valve actuates to its isolation position on manual initiation or on an actual or simulated high radiation signal.u:'he 18 month Frequency maintains consistency with other similar ESFAS instrumentation and valve testing requirements.
In LCO 3.3.6, the Containment Purge and Exhaust WaG STS B 3.9.4-6 Rev.3.0, 03/31/04 Containment Penetrations B 3.9.4 BASES SURVEILLANCE REQUIREMENTS (continued) Isolation instrumentation requires a CHANNEL CHECK every 12 hours and a COT every 92 days to ensure the channel OPERABILITY during refueling operations.
Every 18 months a CHANNEL CALIBRATION is performed.
The system actuation response time is demonstrated every 18 months, during refueling, on a STAGGERED TEST BASIS.
SR 3.6.3.5 demonstrates that the isolation time of each valve is in accordance with the Inservice Testing Program requirements.
These Surveillances performed during MODE 6 will ensure that the valves are capable of closing after a postulated fuel handling accident [involving handling recently irradiated fuel] to limit a release of fission product radioactivity from the containment.
yzzg The SR is modified by a Note stating that this Surveillance is not required to be met for valves in isolated penetrations. The LC0 provides the option to close penetrations in lieu of requiring automatic actuation capability. REFERENCES 1.
GPU Nuclear Safety Evaluation SE-0002000-001, Rev.
0, May 20,1988. 2. FSAR, Section [15.4.5].
: 3. NUREG-0800, Section 15.7.4, Rev. I, July 1981. WOG STS Rev. 3.0.
03/31/04 Containment Penetrations B 3.9.4 BASES SURVEILLANCE REQUIREMENTS (continued)
Isolation instrumentation requires a CHANNEL CHECK every 12 hours and a COT every 92 days to ensure the channel OPERABILITY during refueling operations.
Every 18 months a CHANNEL CALIBRATION is performed.
The system actuation response time is demonstrated every 18 months, during refueling, on a STAGGERED TEST BASIS.SR 3.6.3.5 demonstrates that the isolation time of each valve is in accordance with the Inservice Testing Program requirements.
These Surveillances performed during MODE 6 will ensure that the valves are capable of closing after a postulated fuel handling accident[involving handling recently irradiated fuel]to limit a release of fission product radioactivity from the containment.If')Serf""D The SR is modified by a Note stating that this Surveillance is not required to be met for valves in isolated penetrations.
The LCO provides the option to close penetrations in lieu of requiring automatic actuation capability.
REFERENCES 1.GPU Nuclear Safety Evaluation SE-0002000-001, Rev.0, May 20,1988.2.FSAR, Section[15.4.5].3.NUREG-0800, Section 15.7.4, Rev.1, July 1981.WOGSTS B 3.9.4-7 Rev.3.0, 03/31/04 RHR and Coolant Circulation - High Water Level 6 3.9.5 BASES ACTIONS (continued)
: b. One door in each air lock must be closed, and
: c. Each penetration providing direct access from the containment atmosphere to the outside atmosphere must be either closed by a manual or automatic isolation valve, blind flange, or equivalent, or verified to be capable of being closed by an OPERABLE Containment Purge and Exhaust Isolation System.
With RHR loop requirements not met, the potential exists for the coolant to boil and release radioactive gas to the containment atmosphere. Performing the actions described above ensures that all containment penetrations are either closed or can be closed so that the dose limits are not exceeded. The Completion Time of 4 hours allows fixing of most RHR problems and is reasonable, based on the low probability of the coolant boiling in that time. SURVEILLANCE SR 3.9.5.1 REQUIREMENTS This Surveillance demonstrates that the RHR loop is in operation and circulating reactor coolant. The flow rate is determined by the flow rate necessary to provide sufficient decay heat removal capability and to prevent thermal arid boron stratification in the core.Ehe Frequency of 12 hours is sufficient, considering the flow, temperature, pump control, and alarm indications available to the operator in the control room for monitoring the RHR System. ex C REFERENCES 1 FSAR. Section 15.5.71. WOG STS Rev. 3.0, 03/31/04 RHR and Coolant Circulation
-High Water Level B 3.9.5 BASES ACTIONS (continued) b.One door in each air lock must be closed, and c.Each penetration providing direct access from the containment atmosphere to the outside atmosphere must be either closed by a manual or automatic isolation valve, blind flange, or equivalent, or verified to be capable of being dosed by an OPERABLE Containment Purge and Exhaust Isolation System.With RHR loop requirements not met, the potential exists for the coolant to boil and release radioactive gas to the containment atmosphere.
Performing the actions described above ensures that all containment penetrations are either closed or can be closed so that the dose limits are not exceeded.The Completion Time of 4 hours allows fixing of most RHR problems and is reasonable, based on the low probability of the coolant boiling in that time.SURVEILLANCE REQUIREMENTS SR 3.9.5.1 FSAR, Section[5.5.7J.This Surveillance demonstrates that the RHR loop is in operation and circulating reactor coolant.The flow rate is determined by the flow rate necessary to provide sufficient decay heat removal capability and to prevent thermal and boron stratification in the core.[the Frequency of 12 hours is sufficient, considering the flow, temperature, pump control, and alarm indications available to the operator in the control room for monitoring the RHR System.f-',.1.REFERENCES WOGSTS B 3.9.5-4 Rev.3.0, 03/31/04 RHR and Coolant Circulation - Low Water Level B 3.9.6 BASES ACTIONS (continued)
: c. Each penetration providing direct access from the containment atmosphere to the outside atmosphere must be either closed by a manual or automatic isolation valve, blind flange, or equivalent, or verified to be capable of being closed by an OPERABLE Containment Purge and Exhaust Isolation System.
With RHR loop requirements not met, the potential exists for the coolant to boil and release radioactive gas to the containment atmosphere. Performing the actions stated above ensures that all containment penetrations are either closed or can be closed so that the dose limits are not exceeded.
The Completion Time of 4 hours allows fixing of most RHR problems and is reasonable, based on the low probability of the coolant boiling in that time. SURVEILLANCE SR 3.9.6.1 REQUIREMENTS This Surveillance demonstrates that one RHR loop is in operation and circulating reactor coolant. The flow rate is determined by the flow rate necessary to provide sufficient decay heat removal capability and to ~~d;-/w+~~
I prevent thermal and boron stratification in the core.
In addition, during operation of the RHR loop with the water level in the vicinity of the reactor f L > vessel nozzles, the RHR pump suction requirements must be met.ahe Frequency of 12 hours is sufficient, considering the flow, temperature, ) pump control, and alarm indications available to the operator for monitoring the RHR System in the control room. --c----c- Verification that the required pump is OPERABLE ensures that an additional RCS or RHR pump can be placed in operation, if needed, to maintain decay heat removal and reactor coolant circulation. Verification is performed by verif ing proper breaker alignment and power available to the required pump. the Frequency of 7 days is considered reasonable in view of other administrative controls available and has been shown to be acceptable by operating experience.
c3- -- .--* r/ 7. REFERENCES I. FSAR, Section 15.5.71. CLhst)rtQ WOG STS Rev. 3.0, 03/31/04 RHR and Coolant Circulation
-Low Water Level B 3.9.6 BASES ACTIONS (continued) c.Each penetration providing direct access from the containment atmosphere to the outside atmosphere must be either closed by a manual or automatic isolation valve, blind flange, or equivalent, or verified to be capable of being closed by an OPERABLE Containment Purge and Exhaust Isolation System.With RHR loop requirements not met, the potential exists for the coolant to boil and release radioactive gas to the containment atmosphere.
Performing the actions stated above ensures that all containment penetrations are either closed or can be closed so that the dose limits are not exceeded.The Completion Time of 4 hours allows fixing of most RHR problems and is reasonable, based on the low probability of the coolant boiling in that time.SURVEILLANCE REQUIREMENTS Led/)l-")Y'I:':
I CcJrfeD/l'u">j1-,1.-(V REFERENCES SR 3.9.6.1 This Surveillance demonstrates that one RHR loop is in operation and circulating reactor coolant.The flow rate is determined by the flow rate necessary to provide sufficient decay heat removal capability and to prevent thermal and boron stratification in the core.In addition, during operation of the RHR loop with the water level in the vicinity of the reactor vessel nozzles, the RHR pump suction requirements must be met.Ghe Frequency of 12 hours is sufficient, considering the flow, temperature, pump control, and alarm indications available to the operator formonitoring the RHR System in the control room.
Verification that the required pump is OPERABLE ensures that an additional ReS or RHR pump can be placed in operation, if needed, to maintain decay heat removal and reactor coolant circulation.
Verification is performed by proper breaker alignment and power available to the required pump.[he Frequency of 7 days is considered reasonable in view of other administrative controls available and has been shown to be acceptable by operating experience
..;;: 1.FSAR, Section[5.5.7J.WOGSTS B 3.9.6-4 Rev.3.0, 03/31/04 Refueling Cavity Water Level B 3.9.7 BASES APPLICABILITY LC0 3.9.7 is applicable when moving irradiated fuel assemblies within containment. The LC0 minimizes the possibility of a fuel handling accident in containment that is beyond the assumptions of the safety analysis.
If irradiated fuel assemblies are not present in containment, there can be no significant radioactivity release as a result of a postulated fuel handling accident. Requirements for fuel handling accidents in the spent fuel pool are covered by LC0 3.7.15, "Fuel Storage Pool Water Level." ACTIONS With a water level of < 23 ft above the top of the reactor vessel flange, all operations involving or movement of irradiated fuel assemblies within the containment shall be suspended immediately to ensure that a fuel handling accident cannot occur. The suspension of fuel movement shall not preclude completion of movement of a component to a safe position.
SURVEILLANCE SR 3.9.7.1 REQUIREMENTS Verification of a minimum water level of 23 ft above the top of the reactor vessel flange ensures that the design basis for the analysis of the postulated fuel handling accident during refueling operations is met. Water at the required level above the top of the reactor vessel flange limits the consequences of damaged fuel rods that are postulated to result from a fuel handling accident inside containment (Ref.
2). Le Frequency of 24 hours is based on engineering judgment and is considered adequate in view of the large volume of water and the normal procedural controls of valve positions, which make - -- significant unplanned level changes unlikely.
4---- -- - -. REFERENCES 1. Regulatory Guide 1 .25, March 23, 1972. 2. FSAR, Section [15.4.5].
: 3. NUREG-0800, Section 15.7.4. 4. 10 CFR 100.10. 5. Malinowski, D. D., Bell, M. J., Duhn, E., and Locante, J., WCAP- 7828, Radiological Consequences of a Fuel Handling Accident, December 1971. WOG STS Rev. 3.0, 03131104 BASES APPLICABILITY ACTIONS Refueling Cavity Water Level B 3.9.7 LCO 3.9.7 is applicable when moving irradiated fuel assemblies within containment.
The LCO minimizes the possibility of a fuel handling accident in containment that is beyond the assumptions of the safety analysis.If irradiated fuel assemblies are not present in containment, there can be no significant radioactivity release as a result of a postulated fuel handling accident.Requirements for fuel handling accidents in the spent fuel pool are covered by LCO 3.7.15,"Fuel Storage Pool Water Level." With a water level of<23 ft abovethetop of the reactor vessel flange, all operations involving or movement of irradiated fuel assemblies within the containment shall be suspended immediately to ensure that a fuel handling accident cannot occur.The suspension of fuel movement shall not preclude completion of movement of a component to a safe position.SURVEILLANCE SR 3.9.7.1 REQUIREMENTS Verification of a minimum water level of 23 ft above the top of the reactor vessel flange ensures that the design basis for the analysis of the postulated fuel handling accident during refueling operations is met.Water at the required level above the top of the reactor vessel flange limits the consequences of damaged fuel rods that are postulated to result from a fuel handling accident inside containment (Ref.2). Frequency of 24 hours is based on engineering judgment and is considered adequate in view of the large volume of water and the normal procedural controls of valve positions, which make significant unplanned level changes unlikely.
REFERENCES 1.Regulatory Guide 1.25, March 23, 1972.2.FSAR, Section[15.4.5).3.NUREG-0800, Section 15.7.4.4.10 CFR 100.10.5.Malinowski, D.D., Bell, M.J., Duhn, E., and Locante, J.,7828, Radiological Consequences of a Fuel Handling Accident, December 1971.WaG STS B 3.9.7-2 Rev.3.0, 03/31/04
 
===1.1 Definitions===
PRESSURE AND TEMPERATURE LIMITS REPORT (PTLR)RATED THERMAL POWER (RTP)REACTOR PROTECTIONSYSTEM(RPS)
RESPONSE TIME SHUTDOWNMARGIN(SDM)
&sect;"AGGEREDTESTBASIS THERMAL POWER Definitions 1.1ThePTLRistheunit specific document that provides thereactorvesselpressureand temperaturelimits,includingheatupandcooldownrates,forthe currentreactorvesselfluenceperiod.Thesepressureand temperaturelimitsshall be determinedforeach f1uenceperiodin accordance with Specification 5.6.4.RTPshallbeatotalreactorcoreheat transferratetothe reactorcoolantof[3410]MWt.TheRPSRESPONSETIMEshallbethattimeintervalfromwhenthemonitored parameter exceedsitsRPStrip setpoint atthechannel sensoruntilelectricalpowertotheCEAsdrive mechanismisinterrupted.Theresponsetimemaybemeasuredbymeansofanyseriesofsequential, overlapping,ortotalstepssothattheentireresponsetimeismeasured.Inlieuof measurement,responsetimemaybeverifiedfor selected componentsprovidedthatthe components and methodology for verificationhavebeenpreviouslyreviewedandapprovedbytheNRC.SDMshallbethe instantaneous amount of reactivitybywhichthereactorissubcriticalorwouldbe subcriticalfromitspresentconditionassuming:a.AllfulllengthCEAs(shutdownand regulating)arefullyinsertedexceptforthesingleCEAof highest reactivityworth,whichisassumedtobefully withdrawn.
However,withallCEAsverifiedfullyinsertedbytwo independentmeans,itisnot necessary to accountforastuckCEAintheSDM calculation.WithanyCEAsnotcapable ofbeingfullyinserted,the reactivityworthoftheseCEAsmustbeaccountedforinthe determination ofSDM,and[b.ThereisnochangeinpartlengthCEA position.]
A STAGGEREDTESTBASISshall consistofthetesting of one ofthesystems, subsystems,channels,orother designated componentsduringtheintervalspecifiedbythe SurveillanceFrequency,sothatallsystems, subsystems,channels,or other designated componentsaretestedduring n Surveillance Frequencyintervals,where nisthetotalnumberofsystems, subsystems,channels,orother designated componentsintheassociatedfunction.
THERMALPOWERshallbethetotal reactorcoreheat transferratetothe reactor coolant.CEOGSTS 1.1-5Rev.3.1, 12/01/05 1.1 Definitions PRESSURE AND TEMPERATURE LIMITS REPORT (PTLR)RATED THERMAL POWER (RTP)REACTOR PROTECTION SYSTEM (RPS)RESPONSE TIME SHUTDOWN MARGIN (SDM)&sect;"AGGERED TEST BASIS THERMAL POWER Definitions 1.1 The PTLR is the unit specific document that provides the reactor vessel pressure and temperature limits, including heatup and cooldown rates, forthecurrent reactor vessel fluence period.These pressure and temperature limits shall be determined for each f1uence period in accordance with Specification 5.6.4.RTP shall be a total reactor core heat transfer rate to the reactor coolant of[3410]MWt.The RPS RESPONSE TIME shall be that time interval from when the monitored parameter exceeds its RPS trip setpoint at the channel sensor until electrical power to the CEAs drive mechanism is interrupted.
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.In lieu of measurement, response time may be verified for selected components provided that the components and methodology for verification have been previously reviewed and approved by the NRC.SDMshall be the instantaneous amount of reactivity by which the reactor is subcritical or would be subcritical from its present condition assuming: a.All full length CEAs (shutdown and regulating) are fully inserted except for the single CEA of highest reactivity worth, which is assumed to be fully withdrawn.
However, with all CEAs verified fully inserted by two independent means, it is not necessary to account for a stuck CEA in the SDM calculation.
With any CEAs not capable of being fully inserted, the reactivity worth of these CEAs must be accounted for in the determination of SDM, and[b.There is no change in part length CEA position.]
A STAGGERED TEST BASIS shall consist of the testing of one of the systems, subsystems, channels, or other designated components during the interval specified by the Surveillance Frequency, so that all systems, subsystems, channels, or other designated components are tested during n Surveillance Frequency intervals, where n is the total number of systems, subsystems, channels, or other designated components in the associated function.THERMAL POWER shall be the total reactor core heat transfer rate to the reactor coolant.CEOG STS 1.1-5 Rev.3.1, 12/01/05 SDM (Analog) 3.1.1 3.1 REACTIVITY CONTROL SYSTEMS
 
====3.1.1 SHUTDOWN====
MARGIN (SDM) (Analog)
LC0 3.7.1 SDM shall be within the limits specified in the COLR. APPLICABILITY:
MODES 3,4, and 5. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY A. SDM not within limits. - - - SR 3.1.1.1 COLR. CEOG STS A.l Initiate boration to restore SDM to within limits. Rev. 3.0, 03/31/04 15 minutes SDM (Analog)3.1.1 3.1 REACTIVITY CONTROL SYSTEMS 3.1.1 SHUTDOWN MARGIN (SDM)(Analog)LCO 3.1.1 SDM shall be within the limits specified in the COLR.APPLICABILITY:
ACTIONS MODES 3, 4, and 5.CONDITION A.SOM not within limits.A.1 REQUIRED ACTION Initiate boration to restore SDM to within limits.COMPLETION TIME 15 minutes SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.1.1 CEOG STS Verify 80M to be within the limits specified in the COLR.3.1.1-1 Rev.3.0, 03/31/04 Reactivity Balance (Analog)
 
====3.1.2 SURVEILLANCE====
REQUIREMENTS
-. - SURVEILLANCE SR 3.1.2.1 ..............................
NOTES .............................
I. The predicted reactivity values may be adjusted (normalized) to correspond to the measured core reactivity prior to exceeding a fuel burnup of 60 effective full power days (EFPD) after each fuel loading.
: 2. This Surveillance is not required to be performed prior to entry into MODE
: 2. Verify overall core reactivity balance is within + 1.0% Aklk of predicted values. CEOG STS FREQUENCY Prior to entering MODE 1 after fuel loading Rev. 3.0, 03/31/04 Reactivity Balance (Analog)3.1.2 SURVEILLANCE REQUIREMENTS SR 3.1.2.1 SURVEILLANCE
------------------------------NOTES-----------------------------
1.The predicted reactivity values may be adjusted (normalized) to correspond to the measured core reactivity prior to exceeding a fuel burnup of 60 effective full power days (EFPD)after each fuel loading.2.This Surveillance is not required to be performed prior to entry into MODE 2.Verify overall core reactivity balance is within+/-1.0%L1k/k of predicted values.FREQUENCY Prior to entering MODE 1 after fuel loading AND--------N 0 TEOnly required after 60 EFPD fu EFPD CEOG STS 3.1.2-2 Rev.3.0, 03/31/04 CEA Alignment (Analog)
 
====3.1.4 SURVEILLANCE====
REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.4.1 Verify the indicated position of each CEA to be within [7 inches] of all other CEAs in its group.
Within 1 hour following any CEA movement of > [7 inches] SR 3.1.4.2 Verify the CEA motion inhibit is OPERABLE.
E2 days ---.---+ (14 ~se~sj &-. .., SR 3.1.4.3 Verify the CEA deviation circuit is OPERABLE.
-- SR 3.1.4.4 Verify CEA freedom of movement (trippability) by moving each individual CEA that is not fully inserted into the reactor core [5 inches] in either direction.
SR 3.1.4.5 Perform a CHANNEL FUNCTIONAL TEST of the E8 months reed switch position transmitter channel.
6:GI3 SR 3.1.4.6 Verify each CEA drop time is < [3.1] seconds. Prior to reactor criticality, after each removal of the reactor head CEOG STS Rev. 3.0, 03/31/04 SURVEILLANCE REQUIREMENTS CEA Alignment (Analog)3.1.4 SURVEILLANCE FREQUENCY SR 3.1.4.1 Verify the indicated position of each CEA to be Within 1 hour within[7 inches]of all other CEAs in its group.following any CEA movement of>[7 inches]AND@hours 1 SR 3.1.4.2 Verify the CEA motion inhibit is OPERABLE. days l SR 3.1.4.3 Verify the CEA deviation circuit is OPERABLE.@2-t'Sf'rllJ
-.,.''<*.*.,"".SR 3.1.4.4 Verify CEA freedom of movement (trippability) by moving each individual CEA that is not fully inserted into the reactor core[5 inches]in either direction.
SR 3.1.4.5 Perform a CHANNEL FUNCTIONAL TEST of the reed switch position transmitter channel. SR 3.1.4.6 Verify each CEA drop time is S[3.1]seconds.Prior to reactor criticality, after each removal of the reactor head CEOG STS 3.1.4-3 Rev.3.0, 03/31104 Shutdown CEA Insertion Limits (Analog) 3.1.5 3.1 REACTIVITY CONTROL SYSTEMS 3.1.5 Shutdown Control Element Assembly (CEA) Insertion Limits (Analog)
LC0 3.1.5 All shutdown CEAs shall be withdrawn to 2 [I291 inches. APPLICABILITY:
MODE 1, MODE 2 with any regulating CEA not fully inserted.
ACTIONS CONDITION I REQUIRED ACTION
/ COMPLETION TIME A. One or more shutdown A.l Restore shutdown CEA(s) 2 hours CEAs not within limit. to within limit.
B. Required Action and B.l Be in MODE 3. associated Completion Time not met. 6 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.5.1 Verify each shutdown CEA is withdrawn 2 [I 291 inches. CEOG STS Rev. 3.0, 03/31/04 Shutdown CEA Insertion Limits (Analog)3.1.5 3.1 REACTIVITY CONTROL SYSTEMS 3.1.5 Shutdown Control Element Assembly (CEA)Insertion Limits (Analog)LCO 3.1.5 All shutdown CEAs shall be withdrawn to[129]inches.APPLICABILITY:
ACTIONS MODE 1, MODE 2 with any regulating CEA not fully inserted.---------------------------------------------
NOTE--------------------------------------------
This LCO is not applicable while performing SR 3.1.4.4.CONDITION REQUIRED ACTION COMPLETION TIME A.One or more shutdown A.1 Restore shutdown CEA(s)2 hours CEAs not within limit.to within limit.B.Required Action and B.1 Be in MODE 3.6 hours associated Completion Time not met.SURVEILLANCE REQUIREMENTS SR 3.1.5.1 CEOG STS SURVEILLANCE Verify each shutdown CEA is withdrawn;::::[129]inches.3.1.5-1 FREQUENCY@hours f lnser Rev.3.0, 03/31/04 Regulating CEA Insertion Limits (Analog) 3.1.6 ACTIONS (continued)
CONDITION I REQUIRED ACTION I COMPLETION TIME C. Regulating CEA groups inserted between the long term steady state insertion limit and the transient insertion limit for intervals
> 5 effective full power days (EFPD) per 30 EFPD interval or > 14 EFPD per 365 EFPD. C.l Restore regulating CEA groups to within limits.
2 hours D. PDlL alarm circuit inoperable.
D.l Perform SR 3.1.6.1. I hour @ Once per 4 hours thereafter 6 hours E. Required Action and associated Completion Time not met.
SURVEILLANCE REQUIREMENTS E.1 Be in MODE 3. SR 3.1.6.1 ...............................
NOTE ..............................
Not required to be performed until 12 hours after entry into MODE 2. Verify each regulating CEA group position is within its insertion limits.
CEOG STS Rev. 3.0, 03/31/04 Regulating CEA Insertion Limits (Analog)3.1.6 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME C.Regulating CEA groups C.1 Restore regulating CEA 2 hours inserted between the groups to within limits.long term steady state insertion limit and the transient insertion limit for intervals>
5 effective full power days (EFPD)per 30 EFPD interval or>14 EFPO per 365 EFPO.O.POlL alarm circuit 0.1 Perform SR 3.1.6.1.1 hour inoperable.
AND Once per 4 hours thereafter E.Required Action and E.1 Be in MODE 3.6 hours associated Completion Time not met.SURVEILLANCE REQUIREMENTS SR 3.1.6.1 CEOG STS SURVEILLANCE
-------------------------------NOTE------------------------------
Not required to be performed until 12 hours after entry into MODE 2.Verify each regulating CEA group position is within its insertion limits.3.1.6-2 FREQUENCY@.hours---_..........
_-+----TnSe.r-Rev.3.0, 03/31/04 Regulating CEA Insertion Limits (Analog) 3.1 -6 SURVEILLANCE REQUIREMENTS (continued)
I SURVEILLANCE I FREQUENCY SR 3.1.6.2 Verify the accumulated times during which the regulating CEA groups are inserted beyond the steady state insertion limits but within the transient insertion limits. SR 3.1.6.3 Verify PDlL alarm circuit is OPERABLE.
CEOG STS Rev. 3.0, 03/31/04 Regulating CEA Insertion Limits (Analog)3.1.6 SURVEILLANCE REQUIREMENTS (continued)
SR 3.1.6.2 SR 3.1.6.3 CEOG STS SURVEILLANCE Verify the accumulated times during which the regulating CEA groups are inserted beyond the steady state insertion limits but within the transient insertion limits.Verify POlL alarm circuit is OPERABLE.3.1.6-3 FREQUENCY Rev.3.0, 03/31/04 STE - SDM (Analog) 3.1.7 SURVEILLANCE REQUIREMENTS - SURVEILLANCE SR 3.1.7.1 Verify that the position of each CEA not fully inserted is within the acceptance criteria for available negative reactivity addition.
SR 3.1.7.2 ...............................
NOTE .............................
Not required to be performed during initial power escalation following a refueling outage if SR 3.1.4.6 has been met. Verify that each CEA not fully inserted is capable of full insertion when tripped from at least the 50% withdrawn position.
CEOG STS - FREQUENCY Once within [7 days] prior to reducing SDM to less than the limits of LC0 3.1.1 Rev. 3.0. 03131104 SURVEILLANCE REQUIREMENTS SURVEILLANCE STE-SDM (Analog)3.1.7 FREQUENCY SR 3.1.7.1 SR 3.1.7.2 CEOGSTS Verify that the position of each CEA not fully inserted is within the acceptance criteria for available negative reactivity addition.-------------------------------
NOT E------------------------------
Not required to be performed during initial power escalation following a refueling outage if SR 3.1.4.6 has been met.Verify that each CEA not fUlly inserted is capable of full insertion when tripped from at least the 50%withdrawn position.3.1.7-2 Once within[7 days]prior to reducing SDM to less than the limits of LCO 3.1.1 Rev.3.0, 03/31/04 STE - MODES 1 and 2 (Analog) 3.1.8 3.1 REACTIVITY CONTROL SYSTEMS 3.1.8 Special Test Exceptions (STE) - MODES 1 and 2 (Analog) LC0 3.1.8 During the performance of PHYSICS TESTS, the requirements of: LC0 3.1.3, "Moderator Temperature Coefficient (MTC)," LC0 3.1.4, "Control Element Assembly (CEA) Alignment," LC0 3.1.5, "Shutdown Control Element Assembly (CEA) lnsertion Limits," LC0 3.1.6, "Regulating Control Element Assembly (CEA) Insertion Limits," LC0 3.2.2, "Total Planar Radial Peaking Factor (F;~)," LC0 3.2.3, "Total Integrated Radial Peaking Factor (F:)," and LC0 3.2.4, "AZIMUTHAL POWER TILT (T,)," may be suspended, provided THERMAL POWER is restricted to the test power plateau, which shall not exceed 85% RTP. APPLICABILITY:
MODES 1 and 2 during PHYSICS TESTS.
CONDITION REQUIRED ACTION COMPLETION TIME A. Test power plateau exceeded.
A.l Reduce THERMAL 15 minutes POWER to less than or equal to test power plateau.
B. Required Action and B.1 Suspend PHYSICS TESTS. 1 hour associated Completion Time not met. SURVEILLANCE REQUIREMENTS SURVEILLANCE
/ FREQUENCY SR 3.1.8.1 Verify THERMAL POWER is equal to or lass than Eou? --__I 'the test power plateau.
., r a ~f 4 CEOG STS 3.1.8-1 Rev. 3.0, 03/31/04 STE-MODES 1 and 2 (Analog)3.1.8 3.1 REACTIVITY CONTROL SYSTEMS 3.1.8 Special Test Exceptions (STE)-MODES 1 and 2 (Analog)LCO 3.1.8 During the performance of PHYSICS TESTS, the requirements of: LCO 3.1.3, LCO 3.1.4, LCO 3.1.5, LCO 3.1.6, LCO 3.2.2, LCO 3.2.3, LCO 3.2.4,"Moderator Temperature Coefficient (MTC),""Control Element Assembly (CEA)Alignment,""Shutdown Control Element Assembly (CEA)Insertion Limits,""Regulating Control Element Assembly (CEA)Insertion Limits,""Total Planar Radial Peaking Factor (F;y),""Total Integrated Radial Peaking Factor (F,T)," and"AZIMUTHAL POWER TILT (T q)," APPLICABILITY:
ACTIONS may be suspended, provided THERMAL POWER is restricted to the test power plateau, which shall not exceed 85%RTP.MODES 1 and 2 during PHYSICS TESTS.!CONDITION REQUIRED ACTION COMPLETION TIME A.Test power plateau A.1 Reduce THERMAL 15 minutes exceeded.POWER to less than or equal to test power plateau.---B.Required Action and B.1 Suspend PHYSICS TESTS.1 hour associated Completion Time not met.SURVEILLANCE REQUIREMENTS SR 3.1.8.1 CEOG STS SURVEILLANCE Verify THERMAL POWER is equal to or less than.the test power plateau.3.1.8-1 FREQUENCY Rev.3.0, 03/31/04 SDM (Digital) 3.1.1 3.1 REACTIVITY CONTROL SYSTEMS
 
====3.1.1 SHUTDOWN====
MARGIN (SDM) (Digital)
LC0 3.1.1 SDM shall be within the limits specified in the COLR. APPLICABILITY:
MODES 3, 4, and 5. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. SDM not within limit.
A.l Initiate boration to restore 15 minutes SDM to within limit.
SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.1.1 Verify SDM to be within the limits specified in the 1~4 ho~rsA-+~-~
--. - CEOG STS Rev. 3.0, 03/31/04 SDM (Digital)3.1.1 3.1 REACTIVITY CONTROL SYSTEMS 3.1.1 SHUTDOWN MARGIN (SDM)(Digital)LCO 3.1.1 SDM shaff be within the limits specified in the COLR.APPLICABILITY:
ACTIONS MODES 3, 4, and 5.CONDITION A.SDM not within limit.A.1 REQUIRED ACTION Initiate boration to restore SDM to within limit.COMPLETION TIME 15 minutes SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.1.1 CEOG STS Verify SDM to be within the limits specified in the COLR.3.1.1-1[14 hours---:t"":_I'.nserCI Rev.3.0, 03/31/04 Reactivity Balance (Digital)
 
====3.1.2 SURVEILLANCE====
REQUIREMENTS - - - - P SURVEILLANCE SR 3.1.2.1 -----"*-------------"--------
NOTES ----------------------------
I. The predicted reactivity values may be adjusted (normalized) to correspond to the measured core reactivity prior to exceeding a fuel burnup of 60 effective full power days (EFPD) after each fuel loading.
: 2. This Surveillance is not required to be performed prior to entry into MODE
: 2. Verify overall core reactivity balance is within 1 .O% Ak/k of predicted values. - - FREQUENCY Prior to entering MODE 1 after fuel CEOG STS Rev. 3.0, 03/31/04 Reactivity Balance (Digital)3.1.2 SURVEILLANCE REQUIREMENTS SR 3.1.2.1 CEOG STS SURVEILLANCE
-----------------------------NOTES----------------------------
1.The predicted reactivity values may be adjusted (normalized) to correspond to the measured core reactivity prior to exceeding a fuel burnup of 60 effective full power days (EFPD)after each fuel loading.2.This Surveillance is not required to beperformedprior to entry into MODE 2.Verify overall core reactivity balance is within+/-1.0% of predicted values.3.1.2-2 FREQUENCY Prior to entering MODE 1 after fuel loading AND--------N 0 TEOnly required after 60 EFPD Rev.3.0, 03/31/04 CEA Alignment (Digital)
: 3. I .4 SURVEILLANCE REQUIREMENTS - SURVEILLANCE SR 3.7.4.1 Verify the indicated position of each full and part length CEA is within
[7 inches] of all other CEAs in its group. SR 3.1.4.2 Verify that, for each CEA, its OPERABLE CEA position indicator channels indicate within [5 inches] of each other. SR 3.1.4.3 Verify full length CEA freedom of movement (trippability) by moving each individual full length CEA that is not fully inserted in the core at least
[5 inches]. SR 3.1.4.4 Perform a CHANNEL FUNCTIONAL TEST of each reed switch position transmitter channel.
SR 3.1.4.5 Verify each full length CEA drop time I [3.5] seconds and the arithmetic average of all full length CEA drop times 5 I3.2) seconds. CEOG STS FREQUENCY hours 4, - 1 4 [I81 months f---\ Prior to reactor criticality, after each removal of the reactor head Rev. 3.0, 03/31/04 CEA Alignment (Digital)3.1.4 SURVEILLANCE REQUIREMENTS SR 3.1.4.1 SR 3.1.4.2 SR 3.1.4.3 SURVEILLANCE Verify the indicated position of each full and part length CEA is within[7 inches]of all other CEAs in its group.Verify that, for each CEA, its OPERABLE CEA position indicator channels indicate within[5 inches]of each other.Verify full length CEA freedom of movement (trippability) by moving each individual fuJI length CEA that is not fully inserted in the core at least[5 inches].FREQUENCY SR 3.1.4.4 Perform a CHANNEL FUNCTIONAL TEST of each@8]months f-l reed switch position transmitter channel.
se;.:r1:_________
,""".,J SR 3.1.4.5 CEOG STS Verify each full length CEA drop time[3.5]seconds and the arithmetic average of all full length CEA drop times:::;[3.2J seconds.3.1.4-2 Prior to reactor criticality, after each removal of the reactor head Rev.3.0, 03/31/04 Shutdown CEA Insertion Limits (Digital) 3.1.5 3.1 REACTIVITY CONTROL SYSTEMS 3.1.5 Shutdown Control Element Assembly (CEA) Insertion Limits (Digital)
LC0 3.1.5 All shutdown CEAs shall be withdrawn to 2 [I451 inches. APPLICABILITY: MODE I, MODE 2 with any regulating CEA not fully inserted.
ACTIONS CONDITION A. One or more shutdown CEAs not within limit. B. Required Action and associated Completion Time not met. -. REQUIRED ACTION A.l Restore shutdown CEA(s) to within limit. B.l Be in MODE 3. -. - 9 COMPLETION TIME 2 hours 6 hours SURVEILLANCE REQUIREMENTS - P SURVEILLANCE I FREQUENCY SR 3.1.5.1 Verify each shutdown CEA is withdrawn 2 [I451 inches. CEOG STS Rev. 3.0, 03/31/04 Shutdown CEA Insertion Limits (Digital)3.1.5 3.1 REACTIVITY CONTROL SYSTEMS 3.1.5 Shutdown Control Element Assembly (CEA)Insertion Limits (Digital)LCD 3.1.5 All shutdown CEAs shall be withdrawn to;::':[145]inches.APPLICABILITY:
ACTIONS MODE 1, MODE 2 with any regulating CEA not fully inserted.
---------------------------------._.--------
This LCO is not applicable while performing SR 3.1.4.3.CONDITION REQUIRED ACTION COMPLETION TIME A.One or more shutdown A.1 RestoreshutdownCEA(s) 2 hours CEAs not within limit.to within limit.B.Required Action and B.1 Be in MODE 3.6 hours associated Completion Time not met.SURVEILLANCE REQUIREMENTS SR 3.1.5.1 CEOG STS SURVEILLANCE Verify each shutdown CEA is withdrawn;::.:[145J inches.3.1.5-1 FREQUENCY Rev.3.0, 03/31/04 Regulating CEA Insertion Limits (Digital) 3.1 -6 ACTIONS (continued) 6 hours CONDITION F. Required Actions and associated Completion Times not met. SURVEILLANCE REQUIREMENTS SURVEILLANCE F.l Be in MODE 3. Verify each regulating CEA group position is within its insertion limits. REQUIRED ACTION Verify the accumulated times during which the regulating CEA groups are inserted beyond the steady state insertion limits but within the transient insertion limits.
COMPLETION TIME SR 3.1.6.3 Verify PDlL alarm circuit is OPERABLE. - - - - CEOG STS - - FREQUENCY Ed hours C- \ Rev. 3.0, 03/31/04 Regulating CEA InsertionLimits(Digital)
 
====3.1.6 ACTIONS====
(continued)
CONDITION F.Required Actions and associated Completion Times not met.F.1 REQUIRED ACTION Be in MODE 3.COMPLETION TIME 6 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.6.1 SR 3.1.6.2 SR 3.1.6.3 CEOG STS------------------------------.
NOT E-------------._---------
------Not required to be periormed until 12 hours after entry into MODE 2.Verify each regulating CEA group position is within its insertion limits.Verify the accumulated times during which the regulating CEA groups are inserted beyond the steady state insertion limits but within the transient insertion limits.Verify POlL alarm circuit is OPERABLE.3.1.6-3 Rev.3.0, 03/31/04 Part Length CEA Insertion Limits (Digital)
 
====3.1.7 ACTIONS====
(continued)
I 1 CONDITION REQUIRED ACTION I COMPLETION TIME C. Required Action and associated Completion Time of Condition B not C.1 Reduce THERMAL POWER to 5 20% RTP. 4 hours met. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY CEOG STS Rev. 3.0, 03/31/04 Part Length CEA Insertion Limits (Digital)3.1.7 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME C.Required Action and C.1 associated Completion Time of Condition B not met.Reduce THERMAL POWER to:::;20%RTP.4 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY Verify part length CEA group position.SR 3.1.7.1 f12 hours",")tLnSCf'tt.
i
......_--............
CEOG STS 3.1.7-2 Rev.3.0, 03/31/04 STE - SDM (Digital)
 
====3.1.8 SURVEILLANCE====
REQUIREMENTS SURVEILLANCE SR 3.1.8.1 Verify that the position of each CEA not fully inserted is within the acceptance criteria for available negative reactivity addition. Verify each full length CEA not fully inserted is capable of full insertion when tripped from at least the 50% withdrawn position.
CEOG STS FREQUENCY Once within
[7 days] prior to reducing SDM to less than the limits of LC0 3.1 .I Rev. 3.0, 03131104 SURVEILLANCE REQUIREMENTS SURVEILLANCE STE-SDM (Digital)3.1.8 FREQUENCY SR 3.1.8.1 SR 3.1.8.2 CEOG STS Verify that the position of each CEA not fully inserted is within the acceptance criteria for available negativereactivityaddition.
----------------------.:.--------NOTE------------------------------
Not required to be performed during initial power escalation following a refueling outage if SR 3.1.4.5 has been met.Verify each full length CEA not fully inserted is capable of full insertion when tripped from at least the 50%withdrawn position.3.1.8-2 Once within[7 days]prior to reducing 8DM to less than the limits of LCO 3.1.1 Rev.3.0, 03/31/04 STE - MODES 1 and 2 (Digital)
 
====3.1.9 SURVEILLANCE====
 
FREQUENCY CEOG STS Rev. 3.0, 03131104 STE-MODES 1 and 2 (Digital)3.1.9 SURVEILLANCE REQUIREMENTS SR 3.1.9.1 CEOG STS SURVEILLANCE Verify THERMAL POWER equal to or less than the test power plateau.3.1.9-2 FREQUENCY Rev.3.0, 03/31/04 LHR (Analog)3.2.1 SURVEILLANCE REQUIREMENTS
-----------------------------------------------------------NOTE-----------------------------------------------------------
Either the Excore Detector Monitoring System or the Incore Detector Monitoring System shall be used to determine LHR.SR 3.2.1.1 SR 3.2.1.2 SR 3.2.1.3 CEOG STS SURVEILLANCE
------------------------------NOTE------------------------------
Only required to be met when the Excore Detector Monitoring System is being used to determine LHR.Verify ASI alarm setpoints are within the limits specified in the COLR.------------------------------
NOTES-----------------------------
1.Only required to be met when the Ineore Detector Monitoring System is being used to determine LHR.2.Not required to be performed below 20%RTP.Verify incore detector local power density alarms satisfy the requirements of the core power distribution map, which shall be updated at least once per 31 days of accumulated operation in MODE 1.-----------------------------
NOTES-----------------------------
1.Only required to be met when the Incore Detector Monitoring System is being used to determine LHR.2.Not required to be performed below 20%RTP.Verify incore detector local power density alarm setpoints are less than or equal to the limits specified in the COLR.3.2.1-2 FREQUENCY CIroe';B'j Rev.3.0, 03/31/04 F$ (Analog) 3.2.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.2.2.1 ...............................
NOTE--- --..---- -- ----- me---- ----- -- SR 3.2.2.2 and SR 3.2.2.3 shall be completed each time SR 3.2.2.1 is required.
F; shall be determined by using the incore detectors to obtain a power distribution map with all full length CEAs at or above the long term steady state insertion limit, as specified in the COLR. Verify the value of F; SR 3.2.2.2 Verify the value of F,. SR 3.2.2.3 Verify the value of T,. CEOG STS FREQUENCY Once prior to operation above 70% RTP after each fuel loading Each 31 days of accumulated operation in In accordance with the Frequency requirements of SR 3.2.2.1 In accordance with the Frequency requirements of SR 3.2.2. I Rev. 3.0, 03/31/04 (Analog)3.2.2 SURVEILLANCE REQUIREMENTS SR 3.2.2.1 SURVEILLANCE
-------------------------------NOTE------------------------------
SR 3.2.2.2 and SR 3.2.2.3 shall be completed each time SR 3.2.2.1 is required.shall be determined by using the incore detectors to obtain a power distribution map with all full length CEAs at or above the long term steady state insertion limit, as specified in the COLR.Verify the value of FFREQUENCY Once prior to operation above 70%RTP after each fuel loading AND[Each 31 days of accumulated operation in MODE 1 g:;;;'-1)
SR 3.2.2.2 SR 3.2.2.3 CEOG STS Verify the value of Fxy.Verify the value of T q.3.2.2-2 In accordance with the Frequency requirements of SR 3.2.2.1 In accordance with the Frequency requirements of SR 3.2.2.1 Rev.3.0, 03/31/04 FT (Analog) SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.2.3.1 ...............................
NOTE ------ ----------
---- ----------
SR 3.2.3.2 and SR 3.2.3.3 shall be completed each time SR 3.2.3.1 is required.
F: shall be determined by using the incore detectors to obtain a power distribution map with all full length CEAs at or above the long term steady state insertion limit as specified in the CQLR. -------------*--------------------------------------------------*----
Verify the value of F: . SR 3.2.3.2 Verify the value of F,. SR 3.2.3.3 Verify the value of T,. FREQUENCY Prior to operation
> 70% RTP after each fuel loading
@lJ C _Each 31 days of accumulated operation in 1y~z~i3> In accordance with the Frequency requirements of SR 3.2.3.1 In accordance with the Frequency requirements of SR 3.2.3. I CEOG STS Rev. 3.0, 03/31/04 SURVEILLANCE REQUIREMENTS SURVEILLANCE F r T (Analog)3.2.3 FREQUENCY SR 3.2.3.1 SR 3.2.3.2 SR 3.2.3.3 CEOG STS-------------------------------NOTE------------------------------
SR 3.2.3.2 and SR 3.2.3.3 shall be completed each time SR 3.2.3.1 is required.F r T shall be determined by using the incore detectors to obtain a power distribution map with all full length CEAs at or above the long term steady state insertion limit as specified in the COLR.Verify the value of F r T.Verify the value of Fr.Verify the value of T q*3.2.3-2 Prior to operation>70%RTP after each fuel loading AND[Each 31 days of accumulated operation in In accordance with the Frequency requirements of SR 3.2.3.1 I n accordance with the Frequency requirements of SR 3.2.3.1 Rev.3.0, 03/31/04 Tq (Analog) 3.2.4 ACTIONS (continued)
CONDITION REQUIRED ACTION C. Indicated T, > 0.10. NOTE ....................
All subsequent Required Actions must be completed if power reduction commences prior to restoring T, 5 0.10. C.1 Verify FG and F: are within the limits of LC0 3.2.2 and LC0 3.2.3, respectively.
AND - C.2 Reduce THERMAL POWER to < 50% RTP. AND 7 C.3 Restore T, to 5 [0.03]. SURVEILLANCE REQUIREMENTS COMPLETION TIME 1 hour 2 hours Correct the cause of the out of limit condition prior to increasing THERMAL POWER. Subsequent power operation above 50% RTP may proceed provided that the measured T, is verified I [0.03] at least once per hour for 12 hours, or until verified at 95% RTP SURVEILLANCE I FREQUENCY SR 3.2.4.1 Verify T, is within limits.
CEOG STS 3.2.4-2 Rev. 3.0, 03131104 ACTIONS (continued)
CONDITION C.Indicated T q>0.10.REQUIRED ACTION-------------------N 0 TE--------------------
All subsequent Required Actions must be completed if power reduction commences prior to restoring T q0.10.T q (Analog)3.2.4 COMPLETION TIME C.1 AND C.2 AND C.3 Verify F:r and F r T are within the limits of LCO 3.2.2 and LCO 3.2.3, respectively.
Reduce THERMAL POWER to<50%RTP.Restore T q to[0.03].1 hour 2 hours Correct the cause of the out of limit condition prior to increasing THERMAL POWER.Subsequent power operation above 50%RTP may proceed provided that the measured T q is verified:;
[0.03J at least once per hour for 12 hours, or until verified at 95%RTP SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.4.1 CEOG STS Verify T q is within limits.3.2.4-2@hours__Rev.3.0, 03/31/04 AS1 (Analog) 3.2.5 3.2 POWER DISTRIBUTION LIMITS
 
====3.2.5 AXIAL====
SHAPE INDEX (ASI) (Analog)
LC0 3.2.5 The AS1 shall be maintained within the limits specified in the COLR. APPLICABILITY:
MODE 1 with THERMAL POWER > 20&deg;h RTP ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. AS1 not within limits. / A.l Restore AS1 to within limits.
1 2 hours 6. Required Action and
 
===6.1 Reduce===
THERMAL 4 hours associated Completion POWER to 5 20% RTP. Time not met. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.5.1 CEOG STS Rev. 3.0, 03/31/04 ASI (Analog)3.2.5 3.2 POWER DISTRIBUTION LIMITS 3.2.5 AXIAL SHAPE INDEX (ASI)(Analog)LCO 3.2.5 The ASI shall be maintained within the limits specified in the COLR.APPLICABILITY:
ACTIONS MODE 1 with THERMAL POWER>20%RTP.CONDITION REQUIRED ACTION COMPLETION TIME A.AS'not within limits.A.1 Restore ASI to within limits.2 hours B.Required Action and B.1 Reduce THERMAL 4 hours associated Completion POWER to s 20%RTP.Time not met.SURVEILLANCE REQUIREMENTS SR 3.2.5.1 CEOG STS SURVEILLANCE Verify ASI is within limits specified in the COLR.3.2.5-1 FREQUENCY[&#xa3;2 hours.1.:.':-"""'".
,*....---"-,.*
Rev.3.0, 03/31/04 LHR (Digital)
 
====3.2.1 SURVEILLANCE====
REQUIREMENTS SURVEILLANCE
---------------we--------------
NOTE .............................. Only required to be met when COLSS is out of service. With COLSS in service, LHR is continuously monitored.
-----------+---------------------*4----------------------------------
Verify LHR, as indicated on each OPERABLE local power density channel, is within its limit.
Verify the COLSS margin alarm actuates at a THERMAL POWER equal to or less than the core power operating limit based on LHR. FREQUENCY I? hours e--., CEOG STS Rev. 3.0, 03/31/04 SURVEILLANCE REQUIREMENTS SURVEILLANCE LHR (Digital)3.2.1 FREQUENCY SR 3.2.1.1 SR 3.2.1.2 CEOG STS-------------------------------
NOT E------------------------------
Only required to be met when COLSS is out of service.With COLSS in service, LHR is continuously monitored.
Verify LHR, as indicated on each OPERABLE local power density channel, is within its limit.Verify the COLSS margin alarm actuates at a THERMAL POWER equal to or less than the core power operating limit based on LHR.3.2.1-2 Rev.3.0, 03/31/04 F,, (Digital)
 
====3.2.2 SURVEILLANCE====
REQUIREMENTS - SURVEILLANCE Verify measured F: obtained using the lncore Detector System is equal to or less than the value of F: used in the COLSS and CPCs. CEOG STS FREQUENCY Once after each fuel loading with THERMAL POWER > 40% RTP but prior to operations above 70% RTP Rev. 3.0, 03/31/04 SURVEILLANCE REQUIREMENTS SURVEILLANCE F xy (Digital)3.2.2 FREQUENCY SR 3.2.2.1 CEOG STS Verify measuredobtained using the fneore Detector System is equal to or less than the value ofused in the COLSS and CPCs.3.2.2-2 Onee after each fuel loading with THERMAL POWER>40%RTP but prior to operations above 70%RTP AND{F1 EFPD 6;: thereafter 7-.* t:
Rev.3.0, 03/31/04 T, (Digital)
 
====3.2.3 ACTIONS====
(continued)
CONDITION REQUIRED ACTION COMPLETION TIME C. Required Actions and associated Completion Times not met. 8.3 Restore the measured T, to less than the T, allowance used in the CPCs. C.1 Reduce THERMAL POWER to 120%. Prior to increasing THERMAL POWER -----------
NOTE -----.,---- Correct the cause of the out of limit condition prior to increasing THERMAL POWER. Subsequent power operation
> 50% RTP may proceed provided that the measured T, is verified I [0.10] at least once per hour for 12 hours, or until verified at 2 95% RTP 6 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.3.1 ...............................
NOTE .............................. Only required to be met when COLSS is out of service. With COLSS in service, this parameter is continuously monitored.
.....................................................................
Calculate T, and verify it is within the limit. - SR 3.2.3.2 Verify COLSS azimuthal tilt alarm is actuated at a value less than the T, value used in the CPCs. CEOG STS Rev. 3.0, 03/31/04 T q (Digital)3.2.3 t\CTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME B.3 Restore the measured T q to Prior to increasing less than the T q allowance THERMAL POWER used in the CPCs.-----------NO TE----------
Correct the cause of the out of limit condition prior to increasing THERMAL POWER.Subsequent power operation>
50%RTP may proceed provided that the measured T q is verified$[0.10]at least once per hour for 12 hours, or until verified at 2: 95%RTP
_.C.Required Actions and C.1 Reduce THERMAL 6 hours associated Completion POWER to$20%.Times not met.SURVEILLANCE REQUIREMENTS SR 3.2.3.1 SURVEILLANCE
-------------------------------
NOT E------------------------------
Only required to be met when COLSS is out of service.With COLSS in service, this parameter is continuously monitored.
Calculate T q and verify it is within the limit.FREQUENCY SR 3.2.3.2 Verify COLSS azimuthal tilt alarm is actuated ataT q&sect; value less than the T q value used in the CPCs..
---CEOG STS 3.2.3-2 Rev.3.0, 03/31/04 T, (Digital) 3.2.3 SR 3.2.3.3 Independently confirm the validity of the COLSS calculated T, by use of the incore detectors.
SURVEILLANCE REQUIREMENTS (continued)
CEOG STS SURVEILLANCE Rev. 3.0, 03/31/04 FREQUENCY SURVEILLANCE T q (Digital)3.2.3 FREQUENCY SR 3.2.3.3 CEOG STS Independently confirm the validity of the COLSS calculated T q by use of the incore detectors.
3.2.3-3 Rev.3.0, 03/31/04 DNBR (Digital)
 
====3.2.4 ACTIONS====
(continued)
CONDITION C. Required Action and associated Completion Time not met. REQUIRED ACTION B.2.1 With an adverse trend, restore DNBR to within limit. 13.2.2 With no adverse trend, restore DNBR to within limit. C.l Reduce THERMAL POWER to 5 20% RTP. COMPLETION TIME 1 hour 4 hours 6 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.4.1 ...............................
NOTE .............................. Only required to be met when COLSS is out of service. With COLSS in service, this parameter is continuously monitored.
------------------------+*-------------------------------------------
Verify DNBR, as indicated on all channels, is within the limit of Figure 3.2.4-1 or 3.2.4-2 of the COLR, as applicable.
SR 3.2.4.2 Verify COLSS margin alarm actuates at a THERMAL POWER level equal to or less than the days , o+lY"U *I""-yI core power operating limit based on DNBR.
LI fie. &A) ----- -' -' CEOG STS Rev. 3.0. 03/31/04 DNBR (Digital)3.2.4 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME B.2.1 With an adverse trend, 1 hour restore DN8R to within limit.OR 8.2.2 With no adverse trend, 4 hours restore DNBR to within limit.C.Required Action and C.1 Reduce THERMAL 6 hours associated Completion POWER to::;20%RTP.Time not met.SURVEILLANCE REQUIREMENTS SR 3.2.4.1 SR 3.2.4.2 CEOG STS SURVEILLANCE
-------------------------------NOTE------------------------------
Only required to be met when COLSS is out of service.With COLSS in service, this parameter is continuously monitored.
Verify DNBR, as indicated on all OPERABLE DNBR channels, is within the limit of Figure 3.2.4-1 or 3.2.4-2 of the COLR, as applicable.
Verify COLSS margin alarm actuates at a THERMAL POWER level equal to or less than the core power operating limit based on DNBR.3.2.4-2 FREQUENCY Rev.3.0, 03/31/04 AS1 (Digital) 3.2.5 3.2 POWER DISTRIBUTION LIMITS 3.2.5 AXIAL SHAPE INDEX (ASI) (Digital)
LC0 3.2.5 AS1 shall be within the limits specified in the COLR. APPLICABILITY:
MODE 1 with THERMAL POWER > 20% RTP. ACTIONS CONDITION A. Core average AS1 not within limits.
B. Required Action and associated Completion Time not met. REQUIRED ACTION A.l Restore AS1 to within limits. B.l Reduce THERMAL POWER to 120% RTP. COMPLETION TIME 2 hours - 4 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.5.1 Verify AS1 is within limits.
CEOG STS Rev. 3.0, 03/31/04 3.2 POWER DISTRIBUTION LIMITS 3.2.5 AXIAL SHAPE INDEX (ASI)(Digital)LCO 3.2.5 ASI shall be within the limits specified in the COLR.ASI (Digital)3.2.5 APPLICABILITY:
ACTIONS MODE 1 with THERMAL POWER>20%RTP.CONDITION REQUIRED ACTION COMPLETION TIME A.Core average ASI not A1 Restore ASI to within limits.2 hours within limits.-----,-..
B.Required Action and B.1 Reduce THERMAL 4 hours associated Completion POWER to:"::: 20%RTP.Time not met.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.5.1 CEOG STS Verify ASI is within limits.3.2.5-1 Rev.3.0, 03/31/04 RPS Instrumentation Operating (Analog)
 
====3.3.1 ACTIONS====
(continued)
CONDITION F. Required Action and associated Completion Time not met for Axial Power Distribution and Loss of Load Trip Functions.
G. Required Action and associated Completion Time not met except for Axial Power Distribution or Loss of Load Trip Functions.
REQUIRED ACTION E.2.1 [ Place one affected trip unit in bypass and place the other in trip for each affected trip Function.
E.2.2 Restore one automatic bypass removal channel and the associated trip unit to OPERABLE status for each affected trip Function.
F.l Reduce THERMAL POWER to < 15% RTP. G.1 Be in MODE 3. COMPLETION TIME 1 hour [48] hours ] 6 hours 6 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE
-- FREQUENCY Perform a CHANNEL CHECK of each RPS instrument channel except Loss of Load.
CEOG STS 3.3.1-3 Rev. 3.0, 03131104 RPS Instrumentation
-Operating (Analog)3.3.1 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME E.2.1[Place one affected trip unit 1 hour in bypass and place the other in trip for each affected trip Function.AND E.2.2 Restore one automatic[48]hours]bypass removal channel and the associated trip unit to OPERABLE status for each affected trip Function.F.Required Action and F.1 Reduce THERMAL 6 hours associated Completion POWER to<15%RTP.Time not met for Axial Power Distribution and Loss of Load Trip Functions.
G.Required Action and G.1 Be in MODE 3.6 hours associated Completion Time not met except for Axial Power Distribution or Loss of Load Trip Functions.
SURVEILLANCE REQUIREMENTS NOT E Refer to Table 3.3.1-1 to determine which SR shall be performed for each RPS Function.SR 3.3.1.1 CEOG STS SURVEILLANCE Perform a CHANNEL CHECK of each RPS instrument channel except Loss of Load.3.3.1-3 FREQUENCY Rev.3.0, 03/31/04 RPS Instrumentation - Operating (Analog) SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE
: 2. The daily calibration may be suspended during
' PHYSICS TESTS, provided the calibration is performed upon reaching each major test power plateau and prior to proceeding to the next major test power plateau.
*----------------------------------*-----------------++-------------- Perform calibration (heat balance only) and adjust the excore power range and AT power channels to agree with calorimetric calculation if the absolute difference is 2 [I .5]%. SR 3.3.1.3 ---------------------------+---
NOTE ..............................
Not required to be performed until 12 hours after THERMAL POWER is 2 [20]% RTP. Calibrate the power range excore channels using the incore detectors.
SR 3.3.1.4 Perform a CHANNEL FUNCTIONAL TEST of each RPS channel except Loss of Load and Power Rate of Change.
SR 3.3.1.5 ...............................
NOTE .............................. Neutron detectors are excluded from CHANNEL CALIBRATION.
.....................................................................
Perform a CHANNEL CALIBRATION on excore power range channels.
SR 3.3.1.6 Perform a CHANNEL FUNCTIONAL TEST of each Power Rate of Change channel and each Loss of Load functional unit. FREQUENCY d 24 hours 4 # 1 64 92 days & Once within 7 days prior to each reactor startup CEOG STS 3.3.1-4 Rev. 3.0, 03/31/04 RPS Instrumentation
-Operating (Analog)3.3.1 SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.1.2 SR 3.3.1.3 SR 3.3.1.4 SR 3.3.1.5 SR 3.3.1.6 CEOG STS SURVEILLANCE
---------'---------------------NOTES-----------------------------
1.Not required to be performed until 12 hours after THERMAL POWER is;:::.:[20]%RTP.2.The daily calibration may be suspended during PHYSICS TESTS, provided the calibration is performed upon reaching each major test power plateau and prior to proceeding to the next major test power plateau.Perform calibration (heat balance only)and adjust the excore power range andT power channels to agree with calorimetric calculation if the absolute difference is;:::.:[1.5J%.
OTE------------------------------
Not required to be performed until 12 hours after THERMAL POWER is;:::.:[20J%RTP.Calibrate the power range excore channels using the;ncore detectors.
Perform a CHANNEL FUNCTIONAL TEST of each RPS channel except Loss of Load and Power Rate of Change.-------------------------------NOTE------------------------------
Neutron detectors are excluded from CHANNEL CALIBRATION.
Perform a CHANNEL CALIBRATION on excore power range channels.Perform a CHANNEL FUNCTIONAL TEST of each Power Rate of Change channel and each Loss of Load functional unit.3.3.1-4 FREQUENCY
__(EnsertD Once within 7 days prior to each reactor startup Rev.3.0, 03/31/04 RPS Instrumentation - Operating (Analog) SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE SR 3.3.1.7 Perform a CHANNEL FUNCTIONAL TEST on each automatic bypass removal function.
SR 3.3.1.8 NOTE -----------------------------
Neutron detectors are excluded from CHANNEL CALIBRATION.
-------------------**--------------------*--------------------------- Perform a CHANNEL CALIBRATION of each RPS instrument channel, including bypass removal functions.
Verify RPS RESPONSE TIME is within limits.
CEOG STS FREQUENCY Once within 92 days prior to each reactor startup C [18] months 3 - $81 months on a STAGGERED IE'. ". TEST BASIS 1 C Rev. 3.0, 03/31/04 RPS Instrumentation
-Operating (Analog)3.3.1 SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.1.7 SR 3.3.1.8 SR 3.3.1.9 CEOG STS SURVEILLANCE Periorm a CHANNEL FUNCTIONAL TEST on each automatic bypass removal function.
NOT E Neutron detectors are excluded from CHANNEL CALIBRATION.
Periorm a CHANNEL CALIBRATION of each RPS instrument channel, including bypass removal functions.
-------------------------------
NOT E------------------------------
Neutron detectors are excluded.Verify RPS RESPONSE TIME is within limits.3.3.1-5 FREQUENCY Once within 92 days prior to each reactor startup[f18l months on a..i,..STAGGERED Y')TEST BASIS I i_._"
Rev.3.0, 03/31/04 RPS Instrumentation - Shutdown (Analog)
 
====3.3.2 ACTIONS====
(continued)
CONDITION E. Required Action and associated Completion Time not met. REQUIRED ACTION COMPLETION TIME D.2.2 Restore one bypass [48] hours channel and the associated trip unit to OPERABLE status. - E.l Open all RTCBs. 6 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.2.1 Perform a CHANNEL CHECK of each wide range power channel.
fi hours C-1 SR 3.3.2.4 ...............................
NOTE ..............................
Neutron detectors are excluded from CHANNEL CALIBRATION.
SR 3.3.2.2 Perform a CHANNEL FUNCTIONAL TEST on the Power Rate of Change trip function. - -- -. SR 3.3.2.3 Perform a CHANNEL FUNCTIONAL TEST on each automatic bypass removal function.
Perform a CHANNEL CALIBRATION, including bypass removal functions with Allowable Value 5 [2.6] dpm. @ days7 --,7D z:, ns *2- --I 4*A -- E2 days @rl5erto 6 81 months e-., CEOG STS Rev. 3.0, 03/31/04 RPS Instrumentation
-Shutdown (Analog)3.3.2 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME 0.2.2 Restore one bypass[48]hours channel and the associated trip unit to OPERABLE status.E.Required Action and E.1 Open all RTCBs.6 hours associated Completion Time not met.SURVEILLANCE REQUIREMENTS Perform a CHANNEL FUNCTIONAL TEST on the Power Rate of Change trip function.Perform a CHANNEL CHECK of each wide range power channel.Perform a CHANNEL FUNCTIONAL TEST on each automatic bypass removal function.SR 3.3.2.1 SR 3.3.2.2 SR 3.3.2.3 SURVEILLANCE FREQUENCY@hours 11 2
.
::[h.5 er-l.1.l__._...
--I-'=--'''---,--
'[[2 days__..::..----.-_(insert 1:)SR 3.3.2.4 CEOG STS-------------------------------
NOT E------------------------------
Neutron detectors are excluded from CHANNEL CALIBRATION.
Perform a CHANNEL CALIBRATION, including bypass removal functions with Allowable Value$[2.6]dpm.3.3.2-3&#xa9;8]
+-\
Rev.3.0, 03/31/04 RPS Logic and Trip Initiation (Analog) ACTIONS (continued)
CONDITION D. Two channels of Manual Trip, RTCBs, or lnitiation Logic affecting the same trip leg inoperable.
E. Required Action and associated Completion Time of Condition A, B, or D not met. One or more Functions with two or more Manual Trip, Matrix Logic, lnitiation Logic, or RTCB channels inoperable for reasons other than Condition A or D. REQUIRED ACTION D.l Open the affected RTCBs. Be in MODE 3. Open all RTCBs. SURVEILLANCE REQUIREMENTS COMPLETION TIME Immediately 6 hours 6 hours SURVEILLANCE SR 3.3.3.1 Perform a CHANNEL FUNCTIONAL TEST on each RTCB channel.
SR 3.3.3.2 Perform a CHANNEL FUNCTIONAL TEST on each RPS Logic channel.
SR 3.3.3.3 Perform a CHANNEL FUNCTIONAL TEST on each RPS Manual Trip channel.
CEOG STS FREQUENCY Once within 7 days prior to each reactor startup Rev. 3.0, 03/31/04 RPS Logic and Trip Initiation (Analog)3.3.3 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME D.Two channels of Manual D.1 Open the affected RTCBs.Immediately Trip, RTCBs, or Initiation Logic affecting the same trip leg inoperable.
E.Required Action and E.1 Be in MODE 3.6 hours associated Completion Time of Condition A, B, AND or 0 not met.E.2 Open all RTCBs.6 hours OR One or more Functions with two or more Manual Trip, Matrix Logic, Initiation Logic, or RTCB channels inoperable for reasons other than Condition A or D.SURVEILLANCE REQUIREMENTS SR 3.3.3.1 SR 3.3.3.2 SR 3.3.3.3 SURVEILLANCE Perform a CHANNEL FUNCTIONAL TEST on each RTCB channel.Perform a CHANNEL FUNCTIONAL TEST on each RPS Logic channel.Perform a CHANNEL FUNCTIONAL TEST on each RPS Manual Trip channel.FREQUENCY Once within 7 days prior to each reactor startup-------,,,-------
CEOG STS 3.3.3-2 Rev.3.0, 03/31/04 RPS Logic and Trip Initiation (Analog) 3.3.3 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.3.3.4 [ Perform a CHANNEL FUNCTIONAL TEST, including separate verification of the undervoltage and shunt trips, on each RTCB channel. CEOG STS Rev. 3.0, 03/31/04 SURVEILLANCE RPS Logic and Trip Initiation (Analog)3.3.3 FREQUENCY SR 3.3.3.4[Perform a CHANNEL FUNCTIONAL TEST, IE 8J months]including separate verification of the undervoltageand shunt trips, on each RTCB channel.__
CEOG STS Rev.3.0,03/31/04 ESFAS Instrumentation (Analog)
 
====3.3.4 ACTIONS====
(continued)
CONDITION F. Required Action and associated Completion Time not met. REQUIRED ACTION E.2.2 [ Restore one bypass channel and the associated trip unit to OPERABLE status for each affected trip Function.
F.l Be in MODE 3. AND F.2 Be in MODE 4. COMPLETION TlME 48 hours ] 6 hours [I 21 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.4.1 Perform a CHANNEL CHECK of each ESFAS instrument channel.
SR 3.3.4.2 Perform a CHANNEL FUNCTIONAL TEST of ESFAS instrument channel.
-- ?
* SR 3.3.4.3 Perform a CHANNEL FUNCTIONAL TEST on each Once within automatic bypass removal function.
92 days prior to each reactor startup SR 3.3.4.4 Perform a CHANNEL CALIBRATION of each ESFAS instrument channel, including bypass removal functions.
SR 3.3.4.5 Verify ESF RESPONSE TIME is within limits. TEST BASIS GJ- - CEOG STS 3.3.4-3 Rev. 3.0, 03/31/04 ESFAS Instrumentation (Analog)3.3.4 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME E.2.2[Restore one bypass 48 hours]channel and the associated trip unit to OPERABLE status for each affected trip Function.F.Required Action and F.1 Be in MODE 3.6 hours associated Completion Time not met.AND F.2 Be in MODE 4.[12J hours SURVEILLANCE REQUIREMENTS SR 3.3.4.1 SR 3.3.4.2 SURVEILLANCE Perform a CHANNEL CHECK of each ESFAS instrument channel.Perform a CHANNEL FUNCTIONAL TEST of each ESFAS instrument channel.FREQUENCY SR 3.3.4.3 SR 3.3.4.4 SR 3.3.4.5 CEOG STS Perform a CHANNEL FUNCTIONAL TEST on each automatic bypass removal function.Perform a CHANNEL CALIBRATION of each ESFAS instrument channel, including bypass removal functions.
Verify ESF RESPONSE TIME is within limits.3.3.4-3 Once within 92 days prior to each reactor startupf[181 months on aLSTAGGEREDTEST BASIS.
Rev.3.0, 03/31/04 ESFAS Logic and Manual Trip (Analog) ACTIONS (continued)
CONDITION D. One or more Functions with two Manual Trip or Actuation Logic channel inoperable except AFAS. Required Action and associated Completion Time of Condition C not met. REQUIRED ACTION D.l Be in MODE 3. AND D.2 Be in MODE 5. COMPLETION TIME 6 hours hours SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.3.5.1 ----------------------+-------
NOTES .............................
: 1. Testing of Actuation Logic shall include verification of the proper operation of each initiation relay.
: 2. Relays associated with plant equipment that cannot be operated during plant operation are only required to be tested during each MODE 5 entry exceeding 24 hours unless tested during the previous 6 months. - FREQUENCY Perform a CHANNEL FUNCTIONAL TEST on each ESFAS logic channel.
SR 3.3.5.2 Perform a CHANNEL FUNCTIONAL TEST on each ESFAS Manual Trip channel. CEOG STS Rev. 3.0, 03/31/04 ESFAS Logic and Manual Trip (Analog)3.3.5 ACTIONS (continued)
D.One or more Functions D.1 Be in MODE 3.with two Manual Trip or Actuation Logic channel AND inoperable except AFAS.CONDITION 0.2 Required Action and associated Completion Time of Condition C not met.SURVEILLANCE REQUIREMENTS REQUIRED ACTION Be in MODE 5.COMPLETION TIME 6 hours 36 hours SURVEILLANCE FREQUENCY SR 3.3.5.1 SR 3.3.5.2 CEOG STS NOTES-----------------------------
1.Testing of Actuation Logic shall include verification of the proper operation of each initiation relay.2.Relays associated with plant equipment that cannot be operated during plant operation are only required to be tested during each MODE 5 entry exceeding 24 hours unless tested during the previous 6 months.Perform a CHANNEL FUNCTIONAL TEST on each ESFAS logic channel.Perform a CHANNEL FUNCTIONAL TEST on each ESFAS Manual Trip channel.3.3.5-2 (192]days.(:- I\,*\Ser-Rev.3.0, 03/31/04 DG - LOVS (Analog)
 
====3.3.6 ACTIONS====
(continued)
CONDITION C. One or more Functions with more than two channels inoperable.
D. Required Action and associated Completion Time not met. REQUIRED ACTION B.2.1 Place one channel in bypass and the other channel in trip. AND B.2.2 Restore one channel to OPERABLE status.
C.1 Restore all but two channels to OPERABLE status. D.l Enter applicable Conditions and Required Actions for the associated DG made inoperable by DG - LOVS instrumentation. COMPLETION TIME I hour [48] hours 1 hour Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.6.1 [ Perform CHANNEL CHECK.
hours-] SR 3.3.6.2 Perform CHANNEL FUNCTIONAL TEST. CEOG STS Rev. 3.0, 03/31/04 DG-LOVS (Analog)3.3.6 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME B.2.1 Place one channel in 1 hour bypass and the other channel in trip.AND B.2.2 Restore one channel to[48J hours OPERABLE status.C.One or more Functions C.1 Restore all but two 1 hour with more than two channels to OPERABLE channels inoperable.
status.D.Required Action and 0.1 Enter applicable Conditions Immediately associated Completion and Required Actions for Time not met.the associated DG made inoperable by DG-LOVS instrumentation.
SURVEILLANCE REQUIREMENTS SR 3.3.6.1 SR 3.3.6.2 CEOG STS SURVEILLANCE
[Perform CHANNEL CHECK.Perform CHANNEL FUNCTIONAL TEST.3.3.6-2 FREQUENCY Rev.3.0, 03/31/04 DG - LOVS (Analog) SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE SR 3.3.6.3 Perform CHANNEL CALIBRATION with setpoint Allowable Values as follows: a. Degraded Voltage Function 2 [3180] V and I [3220] V Time delay:
r [ ] seconds and I [ ] seconds at
[ ] V and b. Loss of Voltage Function 2 [3180] V and 5 [3220] V Time delay: r [ ] seconds and 5 [ ] seconds at [ IV. FREQUENCY CEOG STS Rev. 3.0, 03/31/04 SURVEILLANCE DG-LOVS (Analog)3.3.6 FREQUENCY SR 3.3.6.3 CEOG STS Perform CHANNEL CALIBRATION with setpoint Allowable Values as follows: a.Degraded Voltage Function;;::
[3180]Vand cs;[3220]V Time delay:;;::[]seconds and CS;[]seconds at[]V and b.Loss of Voltage Function 2::[3180]V and CS;[3220]V Time delay::;:::[]seconds and CS;[]seconds at[]V.3.3.6-3 Rev.3.0, 03/31/04 CPlS (Analog) 3.3.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE Perform a CHANNEL CHECK on each containment radiation monitor channel.
SR 3.3.7.2 Perform a CHANNEL FUNCTIONAL TEST on each containment radiation monitor channel.
Verify CPlS high radiation setpoint is less than or equal to the Allowable Value of [220 mR/hr]. SR 3.3.7.3 -------------------------------NOTE
.............................. Testing of Actuation Logic shall include verification of the proper operation of each initiation relay.
-----+*----------------------------------------*+-------------------- Perform a CHANNEL FUNCTIONAL TEST on each CPlS Actuation Logic channel.
SR 3.3.7.4 Perform a CHANNEL CALIBRATION on each containment radiation monitor channel. Perform a CHANNEL FUNCTIONAL TEST on each CPIS Manual Trip channel.
SR 3.3.7.6 Verify CPlS response time of each containment radiation channel is within limits.
CEOG STS FREQUENCY
[!8] months on a Rev. 3.0, 03/31/04 CPIS (Analog)3.3.7 SURVEILLANCE REQUIREMENTS J SURVEILLANCE FREQUENCY SR 3.3.7.1 Perform a CHANNEL CHECK on each containment
&sect;hours radiation monitor channel.
/t1.'j (J:rI5e.r"../_.,......",P"d,"","'''''
SR 3.3.7.2 Perform a CHANNEL FUNCTIONAL TEST on each containment radiation monitor channel.-,."**","".......
..".c**.."/::::'1'," ,.....,(t.1" , ,I'"','''''..Verify CPIS high radiation setpoint is less than or......
..
.,-equal to the Allowable Value of[220 mR/hr).-SR 3.3.7.3-------------------------------
NOT E----------------------------_.
Testing of Actuation Logic shall include verification of the proper operation of each initiation relay.----_...._...-..-----------------------------------_
..._...-....------------------
Perform a CHANNEL FUNCTIONAL TEST on each
..CPIS Actuation Logic channel.'-::--..-_.".'1, (::L r-*t5 e*..t"'**
.*_....__,......__..__
....,.4:;_SR 3.3.7.4 Perform a CHANNEL CALIBRATION on each (68)months (--...., containment radiation monitor channel.CIrt5 e..-fSR 3.3.7.5 Perform a CHANNEL FUNCTIONAL TEST on each ili 8)months,,_CPIS ManualTripchannel.
6(\se r...._........,"'_.J_::...........'-'-.
SR 3.3.7.6 Verify CPIS response time of each containment8]months on a radiation channel is within limits.TAGGERED CEOG STS 3.3.7-2 Rev.3.0.03/31/04 CRlS (Analog) 3.3.8 ACTIONS (continued)
CONDITION C. CRlS Manual Trip, Actuation Logic, or [one or more required channels of particulateliodine or gaseous] radiation monitors inoperable [in MODE 5 or 63, during movement of [recently] irradiated fuel assemblies. REQUIRED ACTION C.1 --------------
NOTE -------------- Place CREACS in toxic gas protection mode if automatic transfer to toxic gas protection mode inoperable.
------------------*------------------ Place one CREACS train in emergency radiation protection mode.
C.2.1 Suspend movement of [recently] irradiated fuel assemblies.
C.2.2 --------------NOTE Limited plant cooldown or boron dilution is allowed provided the change is accounted for in the calculated SDM. -----------------------+------------- Suspend positive reactivity additions.
COMPLETION TIME lmmediately lmmediately lmmediately SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.8.1 Perform a CHANNEL CHECK on the required k2 hours control room radiation monitor channel. - - - . - -. . - CEOG STS Rev. 3.0, 03/31/04 CRIS (Analog)3.3.8 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME C.CRIS Manual Trip, Actuation Logic, or[one or more required channels of particulate/iodine or gaseous]radiation monitors inoperable
[in MODE 5 or 6], during movement of[recently]
irradiated fuel assemblies.
C.1--------------N0 TE--------------
Place CREACS in toxic gas protection mode if automatic transfer to toxic gas protection mode inoperable.
Place one CREACS train in Immediately emergency radiation protection mode.C.2.1 Suspend movement of[recently]irradiated fuel assemblies.
AND C.2.2--------------N 0 TE Limited plant cooldown or boron dilution is allowed provided the change is accounted for in the calculated SOM.Suspend positive reactivity additions.
SURVEILLANCE REQUIREMENTS SURVEILLANCE Immediately Immediately FREQUENCY_._------_
..._-_....*....-......_-------------------
SR 3.3.8.1 CEOG STS Perform a CHANNEL CHECK on the required control room radiation monitor channel.3.3.8-2 Rev.3.0.03/31104 CRlS (Analog) 3.3.8 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE I FREQUENCY SR 3.3.8.2 Perform a CHANNEL FUNCTIONAL TEST on the required CRlS radiation monitor channel.
Verify CRlS high radiation setpoint is less than or equal to the Allowable Value of [6E4] cpm above normal background.
SR 3.3.8.3 ..............................
NOTES .............................
: 1. Surveillance of Actuation Logic shall include verification of the proper operation of each initiation relay.
: 2. Relays associated with plant equipment that cannot be operated during plant operation are only required to be tested during each MODE 5 entry exceeding 24 hours unless tested within the previous 6 months. Perform a CHANNEL FUNCTIONAL TEST on the required CRlS Actuation Logic channel.
SR 3.3.8.4 Perform a CHANNEL CALIBRATION on the SR 3.3.8.5 required CRlS Manual Trip channel. SR 3.3.8.6 [ Verify response time of required CRlS channel is CEOG STS Rev. 3.0, 03/31/04 CRIS (Analog)3.3.8 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.3.8.2 Perform a CHANNEL FUNCTIONAL TEST on thedays of""" required CRrS radiation monitor channel..l--ID Verify CRIS high radiation setpoint is less than or equal to the Allowable Value of[6E4]cpm above normal background.
SR 3.3.8.3------------------------------NOTES-----------------------------
1.Surveillance of Actuation Logic shall include verification of the proper operation of each initiation relay.2.Relays associated with plant equipment that cannot be operated during plant operation are only required to be tested during each MODE 5 entry exceeding 24 hours unless tested within the previous 6 months.---------------------------------------------------------------------
Perform a CHANNEL FUNCTIONAL TEST on the\E 1 1 days required CRIS Actuation Logic channel.1J:'\Ser: 1)SR 3.3.8.4 Perform a CHANNEL CALIBRATION on the@8]months'-,_.".required CRIS radiation monitor channel.(,
T t','\t'" 1(-+-1..)(i\,.i,,..<' ,....*_..........
"'.!'.._......,.,.SR 3.3.8.5 Perform a CHANNEL FUNCTIONAL TEST on the W 8]monthsrequired CRIS Manual Trip channel.(1 n<:;er-t..1..)
SR 3.3.8.6[Verify response time of required CRIS channel is lii 8}months 1 within limits.(IrtSe....t1)CEOG STS 3.3.8-3 Rev.3.0, 03/31/04 CVCS Isolation Signal (Analog) ACTIONS (continued)
CONDITION REQUIRED ACTION I COMPLETION TIME D. Two Actuation Logic channels inoperable. Required Action and associated Completion Time not met. D.l Be in MODE 3. AND D.2 Be in MODE 5. 6 hours 36 hours SURVEILLANCE REQUIREMENTS
... - SURVEILLANCE SR 3.3.9.1 Perform a CHANNEL CHECK.
SR 3.3.9.2 ..............................
NOTES ............................. 1. Testing of Actuation Logic shall include the verification of the proper operation of each initiation relay.
: 2. Relays associated with plant equipment that cannot be operated during plant operation are only required to be tested during each MODE 5 entry exceeding 24 hours unless tested within the previous 6 months. ..................................................................... Perform a CHANNEL FUNCTIONAL TEST on each CVCS isolation channel with setpoints in accordance with the following Allowable Values: West Penetration Room Pressure - High 2 .5 psig FREQUENCY Letdown Heat Exchanger Room Pressure - High 5 .5 psig CEOG STS Rev. 3.0, 03/31/04 CVCS Isolation Signal (Analog)3.3.9 ACTIONS (continued)
CONDITION D.Two Actuation Logic channels inoperable.
Required Action and associated Completion Time not met.D.1 0.2 REQUIRED ACTION Be in MODE 3.Be in MODE 5.COMPLETION TIME 6 hours 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.9.1 SR 3.3.9.2 Peliorm a CHANNEL CHECK.------------------------------
NOT E S-----------------------------
1.Testing of Actuation Logic shall include the verification of the proper operation of each initiation relay.2.Relays associated with plantequipmentthat cannot be operated during plant operation are only required to be tested during each MODE 5 entry exceeding 24 hours unless tested within the previous 6 months.Peliorm a CHANNEL FUNCTIONAL TEST on each eves isolation channel with setpoints in accordance with the following Allowable Values: West Penetration Room Pressure-High Letdown Heat Exchanger Room Pressure-High s.5 psig s.5 psig___.*, L--_CEOG STS 3.3.9-2 Rev.3.0, 03/31/04 CVCS Isolation Signal (Analog) 3.3.9 SR 3.3.9.3 Perform a CHANNEL CALIBRATION on each SURVEILLANCE REQUIREMENTS (continued) 16 months 6 SURVEILLANCE L CVCS isolation pressure indicating channel. FREQUENCY CEOG STS Rev. 3.0, 03/31/04 SURVEILLANCE CVCS Isolation Signal (Analog)3.3.9 FREQUENCY SR 3.3.9.3 CEOG STS Perform a CHANNEL CALIBRATION on each CVCS isolation pressure indicating channel.3.3.9-3 Rev.3.0, 03/31/04 SBFAS (Analog) 3.3.10 3.3 INSTRUMENTATION 3.3.10 Shield Building Filtration Actuation Signal (SBFAS) (Analog)
LC0 3.3.10 Two channels of SBFAS automatic and two channels of Manual Trip shall be OPERABLE. APPLICABILITY: MODES I, 2, 3, and 4. CONDITION I REQUIRED ACTION I COMPLETION TIME 1 48 hours A. One Manual Trip or Actuation Logic channel inoperable.
A.l Restore the channel to OPERABLE status.
1 B.2 Be in MODE 5. B. Required Action and associated Completion Time not met. 6 hours 6.1 Be in MODE 3. 36 hours SURVEILLANCE REQUIREMENTS SR 3.3.10.1 Perform a CHANNEL FUNCTIONAL TEST on each 1~921 days 6 SBFAS automatic actuation channel.
k C SR 3.3.10.2 SBFAS Manual Trip channel. CEOG STS Rev. 3.0, 03/31/04 SBFAS (Analog)3.3.10 3.3 INSTRUMENTATION 3.3.10 Shield Building Filtration Actuation Signal (SBFAS)(Analog)LCO 3.3.10 APPLICABILITY:
ACTIONS Two channels of SBFAS automatic and two channels of Manual Trip shall be OPERABLE.MODES 1, 2, 3, and 4.CONDITION REQUIRED ACTION COMPLETION TIME A.One Manual Trip or A.1 Restore the channel to 48 hours Actuation Logic channel OPERABLE status.inoperable.
-"---.._......;--._-_..B.Required Action and B.1 Be in MODE 3.6 hours associated Completion Time not met.AND B.2 Be in MODE 5.36 hours SURVEILLANCE REQUIREMENTS SR 3.3.10.1 SR 3.3.10.2 CEOG STS SURVEILLANCE Perform a CHANNEL FUNCTIONAL TEST on each SBFAS automatic actuation channel.Perform a CHANNEL FUNCTIONAL TEST on each SBFAS Manual Trip channel.3.3.10-1 FREQUENCY Rev.3.0, 03/31/04 PAM Instrumentation (Analog) 3.3.1 1 ACTIONS (continued)
CONDITION E. As required by Required Action D.1 and referenced in Table 3.3.11-1.
F. [ As required by Required Action D.l and referenced in Table 3.3.11-1.
REQUIRED ACTION E.l Be in MODE 3. AND E.2 Be in MODE 4. F.1 Initiate action in accordance with Specification
 
====5.6.5. COMPLETION====
 
TIME 6 hours 12 hours Immediately
] SURVEILLANCE REQUIREMENTS SURVEILLANCE 1 FREQUENCY Perform CHANNEL CALIBRATION.
1@8] months % SR 3.3.11.1 Perform CHANNEL CHECK for each required instrumentation channel that is normally energized.
CEOG STS El days 4$--%k (?&I> Rev. 3.1, 12/01/05 PAM Instrumentation (Analog)3.3.11 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME E.As required by Required E.1 Be in MODE 3.6 hours Action D.1 and referenced in AND Table 3.3.11-1.E.2 Be in MODE 4.12 hours F.[As required by F.1Initiateaction in accordance Immediately]
Required Action D.1 and with Specification 5.6.5.referenced in Table 3.3.11-1.SURVEILLANCE REQUIREMENTS
------------------------------------------------------------NOTE-----------------------------------------------------------
These SRs apply to each PAM instrumentation Function in Table 3.3.11-1.SR 3.3.11.1 SR 3.3.11.2 CEOG STS SURVEILLANCE Perform CHANNEL CHECK for each required instrumentation channel that is normally energized.
-------------------------------
NOT E------------------------------
Neutron detectors are excluded from CHANNEL CALIBRATION.
Perform CHANNEL CALIBRATION.
3.3.11-2 FREQUENCY r21 days....,\.(Ir1sertl-;
U2 8]monthsRev.3.1,12/01/05 Remote Shutdown System (Analog) 3.3.12 3.3 INSTRUMENTATION 3.3.12 Remote Shutdown System (Analog)
LC0 3.3.12 The Remote Shutdown System Functions shall be OPERABLE.
APPLICABILITY:
MODES 1, 2, and 3. CONDITION A. One or more required Functions inoperable.
B. Required Action and associated Completion Time not met. -- REQUIRED ACTION A.l Restore required Functions to OPERABLE status.
B.1 Be in MODE 3. AND B.2 Be in MODE 4. COMPLETION TIME 30 days 6 hours [I 21 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE I FREQUENCY SR 3.3.12.1 [ Perform CHANNEL CHECK for each required SR 3.3.12.2 Verify each required control circuit and transfer I months switch is capable of performing the intended
"? - function. - - CEOG STS Rev. 3.0, 03131104 Remote Shutdown System (Analog)3.3.12 3.3 INSTRUMENTATION 3.3.12 Remote Shutdown System (Analog)LCO 3.3.12 APPLICABILITY:
The Remote Shutdown System Functions shall be OPERABLE.MODES 1, 2, and 3.ACTIONS-----------
****-------------------------------------------
NOT E-----------------------------------
***---------------------
Separate Condition entry is allowed for each Function.CONDITION REQUIRED ACTION COMPLETION TIME A.One or more required A.1 Restore required Functions 30 days Functions inoperable.
to OPERABLE status.B.Required Action and B.1 Be in MODE 3.6 hours associated Completion Time not met.AND B.2 Be in MODE 4.[12]hours SURVEILLANCE REQUIREMENTS SR 3.3.12.1 SR 3.3.12.2 CEOG STS SURVEILLANCE
[Perform CHANNEL CHECK for each required instrumentation channel that is normally energized.
Verify each required control circuit and transfer switch is capable of performing the intended function.3.3.12-1 FREQUENCY@8]months.*."'"'-,,,.C'X.r'oc.
Rev.3.0, 03/31/04 Remote Shutdown System (Analog) 3.3.12 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE SR 3.3.12.3 NOTE ----------------------------- Neutron detectors are excluded from the CHANNEL CALIBRATION.
----------------d--*-----*------------------------------------------
Perform CHANNEL CALIBRATION for each required instrumentation channel. SR 3.3.12.4 [ Perform CHANNEL FUNCTIONAL TEST of the reactor trip circuit breaker openlclosed indication.
CEOG STS FREQUENCY
[I81 months f7 .-- '& ' 18 months
] 1 Rev. 3.0, 03131104 SURVEILLANCE Remote Shutdown System (Analog)3.3.12 FREQUENCY SR 3.3.12.3 SR 3.3.12.4 CEOG STS------------------------------NOTE-----------------------------
Neutron detectors are excluded from the CHANNEL CALIBRATION.
Perform CHANNEL CALIBRATION for each required instrumentation channel.[Perform CHANNEL FUNCTIONAL TEST of the reactor trip circuit breaker open/closed indication.
3.3.12-2 Rev.3.0, 03/31/04
[Logarithmic]
Power Monitoring Channels (Analog) SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.3.13.1 Perform CHANNEL CHECK. SR 3.3.13.2 Perform CHANNEL FUNCTIONAL TEST Perform CHANNEL CALIBRATION.
FREQUENCY d 11_2 hours &-.. (~nsert 2) 4: * ""- b8] months Fw--*'"---
\-~r~erti'
,-,e-' CEOG STS Rev. 3.0, 03/31/04
[Logarithmic]
Power Monitoring Channels (Analog)3.3.13 SURVEILLANCE REQUIREMENTS SR 3.3.13.1 SR 3.3.13.2 SR 3.3.13.3 CEOG STS SURVEILLANCE Perform CHANNEL CHECK.Perform CHANNEL FUNCTIONAL TEST.
Neutron detectors are excluded from CHANNEL CALIBRATION.
Perform CHANNEL CALIBRATION.
3.3.13-2 FREQUENCY r:;', L!.?hours (,-"-r-n-s-e-r+--t1.-"".j Rev.3.0, 03/31/04 RPS Instrumentation - Operating (Digital)
 
====3.3.1 SURVEILLANCE====
 
SR 3.3.1.1 Perform a CHANNEL CHECK of each RPS instrument channel except Loss of Load. SR 3.3.1.2 ------------------------*+---*-
NOTE .............................. Not required to be performed until 12 hours after THERMAL POWER 2 70% RTP. Verify total Reactor Coolant System (RCS) flow rate as indicated by each CPC is less than or equal to the RCS total flow rate. If necessary, adjust the CPC addressable constant flow coefficients such that each CPC indicated flow is less than or equal to the RCS flow rate.
SR 3.3.1.3 Check the CPC auto restart count.
SR 3.3.1.4 NOTES .............................
I. Not required to be performed until 12 hours after THERMAL POWER 2 20% RTP. 2. The daily calibration may be suspended during PHYSICS TESTS, provided the calibration is performed upon reaching each major test power plateau and prior to proceeding to the next major test power plateau.
----+*--------------------------------------------------------------- Perform calibration (heat balance only) and adjust the linear power level signals and the CPC addressable constant multipliers to make the CPC AT power and CPC nuclear power calculations agree with the calorimetric, if the absolute difference is 2 [2]%. CEOG STS FREQUENCY CI 12 hours % r" E4 hours Rev. 3.0, 03/31/04 RPS Instrumentation
-Operating (Digital)3.3.1 SURVEILLANCE REQUIREMENTS Refer to Table 3.3.1-1 to determine which SR shall be performed for each RPS Function.SR 3.3.1.1 SR 3.3.1.2 SR 3.3.1.3 SR 3.3.1.4 CEOG STS SURVEILLANCE Perform a CHANNEL CHECK of each RPS instrument channel except Loss of Load.-------------------------------
NOTE------------------------------
Not required to be performed until 12 hours after THERMAL POWER70%RTP.Verify total Reactor Coolant System (RCS)flow rate as indicated by each CPC is less than or equal to the ReS total flow rate.If necessary.
adjust the CPC addressable constant flow coefficients such that each CPC indicated flow is less than or equal to the RCS flow rate.Check the CPC auto restart count.
NOTES-----------------------------
1.Not required to be performed until 12 hours after THERMAL POWER 2:: 20%RTP.2.The daily calibration may be suspended during PHYSICS TESTS, provided the calibration is performed upon reaching each major test power plateau and prior to proceeding to the next major test power plateau.Perform calibration (heat balance only)and adjust the linear power level signals and the epc addressable constant multipliers to make the cpe d T power and epe nuclear power calculations agree with the calorimetric, iftheabsolute difference is 2:[2]%.3.3.1-3 FREQUENCY U?hOUrS(TY1st:,;=[1
.-
Rev.3.0, 03/31/04 RPS Instrumentation - Operating (Digital)
 
====3.3.1 SURVEILLANCE====
REQUIREMENTS (continued)
SURVEILLANCE I Verify total RCS flow rate indicated by each CPC is less than or equal to the RCS flow determined by calorimetric calculations.
SR 3.3.1.6 ...............................
NOTE .............................. Not required to be performed until 12 hours after THERMAL POWER 2 15% RTP. Verify linear power subchannel gains of the excore detectors are consistent with the values used to establish the shape annealing matrix elements in the CPCs. SR 3.3.1.7 ----*-------------------------
NOTES .............................
I. The CPC CHANNEL FUNCTIONAL TEST shall include verification that the correct values of addressable constants are installed in each OPERABLE CPC.
: 2. Not required to be performed for logarithmic power level channels until 2 hours after reducing logarithmic power below 1E-4% and only if reactor trip circuit breakers (RTCBs) are closed. Perform CHANNEL FUNCTIONAL TEST on each channel except Loss of Load and power range neutron flux.
days CEOG STS Rev. 3.0, 03/31/04 RPS Instrumentation
-Operating (Digital)3.3.1 SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.1.5 SR 3.3.1.6 SR 3.3.1.7 CEOG STS SURVEILLANCE
-------------------------------
NOT E------------------------------
Not required to be performed until 12 hours after THERMAL POWER 2: 70%RTP.Verify total RCS flow rate indicated by each CPC is less than or equal to the RCS flow determined by calorimetric calculations.
-------------------------------
NOT E------------------------------
Not required to be performed until 12 hours after THERMAL POWER 2: 15%RTP.Verify linear power subchannel gains of the excore detectors are consistent with the values used to establish the shape annealing matrix elements in the CPCs.------------------------------
NOTES-----------------------------
1.The CPC CHANNEL FUNCTIONAL TEST shall include verification that the correct values of addressable constants are installed in each OPERABLE CPC.2.Not required to be performed for logarithmic power level channels until 2 hours after reducing logarithmic power below 1E-4%and only if reactor trip circuit breakers (RTCBs)are closed.Perform CHANNEL FUNCTIONAL TEST on each channel except Loss of Load and power range neutron flux.3.3.1-4 FREQUENCY
&sect;days......6:--;se!1JJ Rev.3.0, 03/31/04 RPS Instrumentation - Operating (Digital)
SR 3.3.1.9 ...............................
NOTE ..............................
[ Not required to be performed until 2 hours after THERMAL POWER 2 55% RTP. ------*---------------------------------+----------------------------
Perform CHANNEL FUNCTIONAL TEST for Loss of Load Function.
SR 3.3.1.10 ---------------------------+---
NOTE .............................. Neutron detectors are excluded from CHANNEL CALIBRATION.
------------------------------------------------------------+-------- Perform CHANNEL CALIBRATION on each channel, including bypass removal functions.
SR 3.3.1.11 Perform a CHANNEL FUNCTIONAL TEST on each CPC channel. SR 3.3.1.12 Using the incore detectors, verify the shape annealing matrix elements to be used by the CPCs. SR 3.3.1.13 Perform a CHANNEL FUNCTIONAL TEST on each automatic bypass removal function.
CEOG STS FREQUENCY El 81 months (;l Once after each refueling prior to exceeding 70% RTP Once within 92 days prior to each reactor startup Rev. 3.0, 03/31/04 SURVEILLANCE RPS Instrumentation
-Operating (Digital)3.3.1 FREQUENCY SR 3.3.1.8 SR 3.3.1.9-------------------------------NOTE------------------------------
Neutron detectors are excluded from the CHANNEL CALIBRATION.
Perform CHANNEL CALIBRATION of the power range neutron flux channels.-------------------------------NOTE------------------------------
[Not required to be performed until 2 hours after THERMAL POWER 2': 55%RTP.
SR 3.3.1.10Perform CHANNEL FUNCTIONAL TEST for Loss of[I2 days]Load Function.-------------------------------
NOT E------------------------------
Neutron detectors are excluded from CHANNEL CALIBRATION.
SR 3.3.1.11 SR 3.3.1.12 SR 3.3.1.13 CEOG STS Perform CHANNEL CALIBRATION on each channel, inclUding bypass removal functions.
Perform a CHANNEL FUNCTIONAL TEST on each CPC channel.Using the incore detectors, verify the shape annealing matrix elements to be used by the CPCs.Perform a CHANNEL FUNCTIONAL TEST on each automatic bypass removal function.3.3.1-5 Once after each refueling prior to exceeding 70%RTP Once within 92 days prior to each reactor startup Rev.3.0, 03/31/04 RPS Instrumentation - Operating (Digital)
 
====3.3.1 SURVEILLANCE====
 
REQUIREMENTS (continued)
SURVEILLANCE Verify RPS RESPONSE TIME is within limits CEOG STS FREQUENCY El81 months on a Rev. 3.0, 03131104 SURVEILLANCE RPS Instrumentation
-Operating (Digital)3.3.1 FREQUENCY SR 3.3.1.14 CEOG STS------------------------------NOTE------------------------------
Neutron detectors are excluded.Verify RPS RESPONSE TIME is within limits.3.3.1-6 f[181 months on a TEST BASIS Rev.3.0, 03/31/04 ACTIONS (continued)
A CONDITION C. One automatic bypass removal channel
 
inoperable.
D. Two automatic bypass removal channels inoperable.
E. Required Action and associated Completion Time not met.
RPS Instrumentation - Shutdown (Digital)
 
====3.3.2 REQUIRED====
ACTION
-- Disable bypass channel. Place affected automatic trip channel in bypass or trip. C.2.2 Restore bypass removal channel and associated automatic trip channel to OPERABLE status.
I Disable bypass channels.
D.2 Place one affected automatic trip channel in bypass and place the other in trip. E.l Open all RTCBs. SURVEILLANCE REQUIREMENTS COMPLETION 1 hour 1 hour Prior to entering MODE 2 following next MODE 5 entry I hour 1 hour 1 hour SURVEILLANCE I FREQUENCY CEOG STS Rev. 3.0, 03/31/04 RPS Instrumentation
-Shutdown (Digital)3.3.2 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION C.One automatic bypass C.1 Disable bypass channel.1 hour removal channel inoperable.
OR C.2.1 Place affected automatic 1 hour trip channel in bypass or trip.AND C.2.2 Restore bypass removal Prior to entering channel and associated MODE 2 following automatic trip channel to next MODE 5 entry OPERABLE status..
D.Two automatic bypass D.1 Disable bypass channels.1 hour removal channels inoperable.
OR D.2 Place one affected 1 hour automatic trip channel in bypass and place the other in trip.--_...E.Required Action and E.1 Open all RTCBs.1 hour associated Completion Time not met.SURVEILLANCE REQUIREMENTS SR 3.3.2.1 CEOG STS SURVEILLANCE Perform a CHANNEL CHECK of each logarithmic power channel.3.3.2-2 FREQUENCY Rev.3.0, 03/31/04 RPS Instrumentation - Shutdown (Digital) SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE SR 3.3.2.2 Perform a CHANNEL FUNCTIONAL TEST on each logarithmic power channel.
SR 3.3.2.3 Perform a CHANNEL FUNCTIONAL TEST on each automatic bypass removal function.
-- - SR 3.3.2.4 -------------------------------NOTE Neutron detectors are excluded from CHANNEL CALIBRATION.
--------d-*--------------------------------**------------------------
Perform a CHANNEL CALIBRATION on each logarithmic power channel, including bypass removal function with Allowable Value for trip channels 5 [.93]%. SR 3.3.2.5 Verify RPS RESPONSE TIME is within limits.
CEOG STS FREQUENCY 92 days t!-- L G> SeGI-Q Once within 92 days prior to each reactor startup C [I81 months on a STAGGERED
+. TEST BASIS Rev. 3.0, 03131104 RPS Instrumentation
-Shutdown (Digital)3.3.2 SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.2.2 SR 3.3.2.3 SR 3.3.2.4 SR 3.3.2.5 CEOG STS SURVEILLANCE Perform a CHANNEL FUNCTIONAL TEST on each logarithmic power channel.Perform a CHANNEL FUNCTIONAL TEST on each automatic bypass removal function.-------------------------------
NOT E------------------------------
Neutron detectors are excluded from CHANNEL CALIBRATION.
Perform a CHANNEL CALIBRATION on each logarithmic power channel, including bypass removal function with Allowable Value for trip channels s[.93]%.Verify RPS RESPONSE TIME is within limits.3.3.2-3 FREQUENCY Once within 92 days prior to each reactor startup r[18]months on a tSTAGGEREDTEST BASIS Rev.3.0, 03/31/04 CEACs (Digital)
 
====3.3.3 ACTIONS====
(continued)
CONDITION D. One or two CEACs with three or more auto restarts during a 12 hour period. REQUIRED ACTION D.l Perform CHANNEL FUNCTIONAL TEST on affected CEAC. E. Required Action and E.l Be in MODE 3. associated Completion Time of Condition B, C, or D not met. SURVEILLANCE COMPLETION TIME 24 hours 6 hours REQUIREMENTS SURVEILLANCE SR 3.3.3.1 Perform a CHANNEL CHECK.
SR 3.3.3.2 Check the CEAC auto restart count.
SR 3.3.3.3 Perform a CHANNEL FUNCTIONAL TEST.
SR 3.3.3.4 Perform a CHANNEL CALIBRATION.
SR 3.3.3.5 Perform a CHANNEL FUNCTIONAL TEST SR 3.3.3.6 Verify the isolation characteristics of each CEAC isolation amplifier and each optical isolator for CEAC to CPC data transfer.
FREQUENCY fi2 hours qdm-CG;rn
@2 days k18] months @ 81 months f7 Gr-fie rt~) CEOG STS Rev. 3.0, 03/31/04 CEACs (Digital)3.3.3 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME D.One or two CEACs with 0.1 Perform CHANNEL 24 hours three or more auto FUNCTIONAL TEST on restarts during a 12 hour affected CEAC.period.E.Required Action and E.1 Be in MODE 3.6 hours associated Completion Time of Condition B, C, or 0 not met.SURVEILLANCE REQUIREMENTS SR 3.3.3.1 SR 3.3.3.2 SR 3.3.3.3 SR 3.3.3.4 SR 3.3.3.5 SR 3.3.3.6 CEOG STS SURVEILLANCE Perform a CHANNEL CHECK.Check the CEAC auto restart count.Perform a CHANNEL FUNCTIONAL TEST.Perform a CHANNEL CALIBRATION.
Perform a CHANNEL FUNCTIONAL TEST.Verify the isolation characteristics of each CEAC isolation amplifier and each optical isolator for CEAC to CPC data transfer.3.3.3-3 FREQUENCY[12 hours 4....--[i8]months Rev.3.0, 03/31/04 RPS Logic and Trip Initiation (Digital) ACTIONS (continued)
CONDITION E. Required Action and associated Completion Time of Condition A, B, or D not met. One or more Functions with more than one Manual Trip, Matrix Logic, lnitiation Logic, or RTCB channel inoperable for reasons other than Condition A or D. REQUIRED ACTION E.l Be in MODE 3. p.NJ E.2 Open all RTCBs. COMPLETION TIME SURVEILLANCE REQUIREMENTS SURVEILLANCE 6 hours 6 hours SR 3.3.4.1 Perform a CHANNEL FUNCTIONAL TEST on each RTCB channel.
SR 3.3.4.2 Perform a CHANNEL FUNCTIONAL TEST on each RPS Logic channel.
SR 3.3.4.3 Perform a CHANNEL FUNCTIONAL TEST, including separate verification of the undervoltage and shunt trips, on each RTCB.
SR 3.3.4.4 Perform a CHANNEL FUNCTIONAL TEST on each RPS Manual Trip channel. CEOG STS FREQUENCY - [31] days (--", # [I 81 months L Once within 7 days prior to each reactor
 
startup Rev. 3.0, 03/31/04 RPS Logic and Trip Initiation (Digital)3.3.4 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME E.1 Be in MODE 3.E.Required Action and associated Completion Time of Condition A, B, or D not met.One or more Functions with more than one Manual Trip, Matrix Logic, Initiation Logic, or RTCB channel inoperable for reasons other than Condition A or D.AND E.2 Open all RTCBs.6 hours 6 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.4.1 SR 3.3.4.2 SR 3.3.4.3 SR 3.3.4.4 CEOG STS Periorm a CHANNEL FUNCTIONAL TEST on each RTCB channel.Periorm a CHANNEL FUNCTIONAL TEST on each RPS Logic channel.Periorm a CHANNEL FUNCTIONAL TEST, including separate verification of the undervoltage and shunt trips, on each RTCB.Periorm a CHANNEL FUNCTIONAL TEST on each RPS Manual Trip channel.3.3.4-2 Once within 7 days prior to each reactor startup Rev.3.0, 03/31/04 ESFAS Instrumentation (Digital) SURVEILLANCE REQUIREMENTS SURVEILLANCE Perform a CHANNEL CHECK of each ESFAS channel. Perform a CHANNEL FUNCTIONAL TEST of each ESFAS channel.
SR 3.3.5.3 Perform a CHANNEL CALIBRATION of each ESFAS channel, including bypass removal functions. SR 3.3.5.4 Verify ESF RESPONSE TIME is within limits.
SR 3.3.5.5 Perform a CHANNEL FUNCTIONAL TEST on each automatic bypass removal channel.
FREQUENCY kl8] months % [I81 months on a F TAGGERED f-i, TEST BASIS Once within 92 days prior to each reactor startup CEOG STS Rev. 3.0, 03/31/04 ESFAS Instrumentation (Digital)3.3.5 SURVEILLANCE REQUIREMENTS SR 3.3.5.1 SR 3.3.5.2 SR 3.3.5.3 SR 3.3.5.4 SR 3.3.5.5 CEOG STS SURVEILLANCE Perform a CHANNEL CHECK of each ESFAS channel.Perform a CHANNEL FUNCTIONAL TEST of each ESFAS channel.Perform a CHANNEL CALIBRATION of each ESFAS channel, including bypass removal functions.
Verify ESF RESPONSE TIME is within limits.Perform a CHANNEL FUNCTIONAL TEST on each automatic bypass removal channel.3.3.5-3 FREQUENCY ([2 days ,'"'"',*,,L
...\,..J r[18]months on a
(--, TEST BASIS l.-TA-rIhc--p,2!Jj Once within 92 days prior to each reactor startup Rev.3.0, 03/31/04 ACTIONS (continued)
CONDITION F. Two Actuation Logic channels inoperable. Required Action and associated Completion Time of Conditions, for Safety Injection Actuation Signal, Containment Isolation Actuation Signal, Recirculation Actuation Signal, or Containment Cooling Actuation Signal not met. ESFAS Logic and Manual Trip (Digital)
 
====3.3.6 REQUIRED====
ACTION Be in MODE 3. Be in MODE 5. COMPLETION TIME 6 hours 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE I FREQUENCY SR 3.3.6.1 -------------------------------NOTE
..............................
Testing of Actuation Logic shall include the verification of the proper operation of each initiation relay. Perform a CHANNEL FUNCTIONAL TEST on each ESFAS logic channel.
CEOG STS Rev. 3.0, 03/31/04 ESFAS Logic and Manual Trip (Digital)3.3.6 ACTIONS (continued)
CONDITION F.Two Actuation Logic channels inoperable.
Required Action and associated Completion Time of Conditions, for Safety Injection Actuation Signal, Containment Isolation Actuation Signal, Recirculation Actuation Signal, or Containment Cooling Actuation Signal not met.F.1 AND F.2 REQUIRED ACTION Be in MODE 3.Be in MODE 5.COMPLETION TIME 6 hours 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.6.1 CEOG STS-------------------------------NOTE------------------------------
Testing of Actuation Logic shall include the verification of the proper operation of each initiation relay.Perform a CHANNEL FUNCTIONAL TEST on each ESFAS logic channel.3.3.6-3 Rev.3.0,03/31/04 ESFAS Logic and Manual Trip (Digital)
 
====3.3.6 SURVEILLANCE====
REQUIREMENTS (continued)
SURVEILLANCE Perform a subgroup relay test of each Actuation Logic channel, which includes the de-energization of each subgroup relay and verification of the OPERABILITY of each subgroup relay.
SR 3.3.6.3 Perform a CHANNEL FUNCTIONAL TEST on each ESFAS Manual Trip channel.
FREQUENCY kl84] days 6. *u CEOG STS Rev. 3.0, 03/31/04 ESFAS Logic and Manual Trip (Digital)3.3.6 SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.6.2 SR 3.3.6.3 CEOG STS SURVEILLANCE
-------------------------------NO TE-----------------------------
Relays exempt from testing during operation shall be tested during each MODE 5 entry exceeding 24 hours unless tested during the previous 6 months.Perform a subgroup relay test of each Actuation Logic channel, which includes the de-energization of each subgroup relay and verification of the OPERABILITY of each subgroup relay.Perform a CHANNEL FUNCTIONAL TEST on each ESFAS Manual Trip channel.3.3.6-4 FREQUENCY r[18J months-E-.-.....'\.Rev.3.0, 03/31/04 DG - LOVS (Digital)
 
====3.3.7 ACTIONS====
(continued)
CONDITION C. One or more Functions with more than two channels inoperable.
D. Required Action and associated Completion Time not met. REQUIRED ACTION
 
===8.2 Place===
one channel in bypass and the other channel in trip. C.l Restore all but two channels to OPERABLE status. D.l Enter applicable Conditions and Required Actions for the associated DG made inoperable by DG - LOVS instrumentation.
COMPLETION TIME 1 hour 1 hour - -- Immediately SURVEILLANCE REQUIREMENTS SR 3.3.7.1 [ Perform CHANNEL CHECK. -- -~ * -. -..- -- SR 3.3.7.2 Perform CHANNEL FUNCTIONAL TEST.
CEOG STS Rev. 3.0, 03/31/04 DG-LOVS (Digital)3.3.7 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME B.2 Place one channel in 1 hour bypass and the other channel in trip.C.One or more Functions C.1 Restore all but two 1 hour with more than two channels to OPERABLE channels inoperable.
status.D.Required Action and D.1 Enter applicable Conditions Immediately associated Completion and Required Actions for Time not met.the associated DG made inoperable by DG-LOVS instrumentation.
SURVEILLANCE REQUIREMENTS
-------_..-..*.,-,.....,_...._---------------
SR 3.3.7.1 SR 3.3.7.2 CEOG STS SURVEILLANCE
[Perform CHANNEL CHECK.Perform CHANNEL FUNCTIONAL TEST.3.3.7-2 FREQUENCY Rev.3.0.03/31/04 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE SR 3.3.7.3 Perform CHANNEL CALIBRATION with setpoint Allowable Values as follows: a. Degraded Voltage Function 2 [3180] V and 5 [3220] V Time delay:
2 [ ] seconds and I [ ] seconds at [ ]!!and b. Loss of Voltage Function r [3180] V and S [3220] V Time delay: 2 [ ] seconds and I [ ] seconds at [ IV. CEOG STS DG - LOVS (Digital)
 
====3.3.7 FREQUENCY====
 
@8] months 4?." Rev. 3.0, 03/31/04 SURVEILLANCE DG-LOVS (Digital)3.3.7 FREQUENCY SR 3.3.7.3 CEOG STS Perform CHANNEL CALIBRATION with setpoint Allowable Values as follows: a.Degraded Voltage Function::?:
[3180J Vand::;[3220J V Time delay:::?:[J seconds and::;[]seconds at[]V and b.Loss of Voltage Function 2':[3180J Vand::;[3220J V Time delay: 2':[J seconds and:;;[]seconds at[]V.3.3.7-3 Rev.3.0, 03/31/04 CPlS (Digital)
 
====3.3.8 ACTIONS====
(continued)
CONDITION CPlS Manual Trip, Actuation Logic, or one or more required channels of radiation monitors inoperable during movement of [recently] irradiated fuel assemblies within containment. REQUIRED ACTION C.l Place and maintain containment purge and exhaust valves in closed position. . C.2 Suspend movement of [recently] irradiated fuel assemblies in containment. SURVEILLANCE REQUIREMENTS SURVEILLANCE
-- - - COMPLETION TIME Immediately Immediately SR 3.3.8.1 Perform a CHANNEL CHECK on required containment area and gaseous radiation monitor channel. SR 3.3.8.2 Perform a CHANNEL CHECK on required containment particulate and iodine radiation monitor channel. Perform a CHANNEL FUNCTIONAL TEST on each required containment radiation monitor channel.
Verify setpoint [Allowable Value] is in accordance with the following: Containment Gaseous Monitor: 5 [2X background] Containment Particulate Monitor: 5 [2X background] Containment Area Gamma Monitor: 5 [325 mR/hr] - FREQUENCY
@2 days f *- '"'t CEOG STS 3.3.8-2 Rev. 3.0, 03/31/04 CPIS (Digital)3.3.8 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME C.CPIS Manual Trip, C.1 Place and maintain Immediately Actuation Logic, or one containment purge and or more required exhaust valves in closed channels of radiation position.monitors inoperable during movement of OR[recently]
irradiated fuel assemblies within C.2 Suspend movement of Immediately containment.
[recently]
irradiated fuel assemblies in containment.
SURVEILLANCE REQUIREMENTS SR 3.3.8.1 SR 3.3.8.2 SR 3.3.8.3 CEOG STS SURVEILLANCE Perform a CHANNEL CHECK on required containment area and gaseous radiation monitor channel.Perform a CHANNEL CHECK on required containment particulate and iodine radiation monitor channel.-------------------------------
NOTE------------------------------
Only required to be met in MODES 1, 2, 3, and 4.Perform a CHANNEL FUNCTIONAL TEST on each required containment radiation monitor channel.Verify setpoint[Allowable Value]is in accordance with the folloWing:
Containment Gaseous Monitor: s::[2X background]
Containment Particulate Monitor: s::[2X background]
Containment Area Gamma Monitor: S;[325 mR/hr]3.3.8-2 FREQUENCY Rev.3.0, 03/31/04 CPlS (Digital)
 
====3.3.8 SURVEILLANCE====
REQUIREMENTS (continued)
SURVEILLANCE SR 3.3.8.4 -------------------------------NOTE
.............................. Only required to be met during CORE ALTERATIONS or during movement of irradiated fuel assemblies within containment.
Perform a CHANNEL FUNCTIONAL TEST on required containment radiation monitor channel.
Verify setpoint [Allowable Value] is in accordance with the following:
Containment Gaseous Monitor: 5 [2X background] Containment Particulate Monitor: < [2X background] Containment Iodine Monitor: 5 [2X background]
Containment Area Gamma Monitor: I [2X background]
SR 3.3.8.5 ...............................
NOTE ------.+------
------- ---------
Surveillance of Actuation Logic shall include the actuation of each initiation relay and verification of the proper operation of each initiation relay.
Perform a CHANNEL FUNCTIONAL TEST on required CPlS Actuation Logic channel.
SR 3.3.8.6 Perform a CHANNEL CALIBRATION on required containment radiation monitor channel.
SR 3.3.8.7 Verify that response time of required CPlS channel is within limits. SR 3.3.8.8 Perform CHANNEL FUNCTIONAL TEST on required CPlS Manual Trip channel. CEOG STS FREQUENCY 71 81 months & - [18] months +-.--, I 1181 months e-,, Rev. 3.0, 03/31/04 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE CPIS (Digital)3.3.8 FREQUENCY SR 3.3.8.4 SR 3.3.8.5 SR 3.3.8.6 SR 3.3.8.7 SR 3.3.8.8 CEOG STS-------------------------------
NOT E------------------------------
Only required to be met during CORE ALTERATIONS or during movement of irradiated fuel assemblies within containment.
Perform a CHANNEL FUNCTIONAL TEST on required containment radiation monitor channel.Verify setpoint[Allowable Value]is in accordance with the following:
Containment Gaseous Monitor:[2X background]
Containment Particulate Monitor:[2X background]
Containment Iodine Monitor: S;[2X background]
Containment Area Gamma Monitor: S;[2X background]
-------------------------------
NOT E Surveillance of Actuation Logic shall include the actuation of each initiation relay and verification of the proper operation of each initiation relay.Perform a CHANNEL FUNCTIONAL TEST on required CPIS Actuation Logic channel.Perform a CHANNEL CALIBRATION on required containment radiation monitor channel.Verify that response time of required CPIS channel is within limits.Perform CHANNEL FUNCTIONAL TEST on required CPIS Manual Trip channel.3.3.8-3@8]months(IYlSe.rtV
@8]months f-.,\
Rev.3.0, 03/31/04 CRlS (Digital)
 
====3.3.9 ACTIONS====
(continued)
CONDITION CRlS Manual Trip, Actuation Logic, or required particulateliodine or gaseous radiation monitors inoperable [in MODE 5 or 61, or during movement of [recently] irradiated fuel assemblies. REQUIRED ACTION c.1 ---------
-- ---- NOTE --------------
Place CREACS in toxic gas protection mode if automatic transfer to toxic gas protection mode inoperable.
--------**--------------+------------ Place one CREACS train in emergency radiation protection mode.
C.2.1 Suspend movement of [recently] irradiated fuel assemblies.
C.2.2 ---------------NOTE
-------------- Limited plant cooldown or boron dilution is allowed provided the change is accounted for in the calculated SDM. ..................................... Suspend positive reactivity additions.
COMPLETION TIME Immediately Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.3.9.1 Perform a CHANNEL CHECK on the required control room radiation monitor channel. CEOG STS FREQUENCY Rev. 3.0, 03/31/04 CRIS (Digital)3.3.9 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME C.CRIS Manual Trip, C.1 Actuation Logic, or required particulate/iodine or gaseous radiation monitors inoperable
[in MODE 5 or 6], or during movement of[recently]
irradiated fuel assemblies.
NOTE Place CREACS in toxic gas protection mode if automatic transfer to toxic gas protection mode inoperable.
Place one CREACS train in Immediately emergency radiation protection mode.C.2.1 Suspend movement of[recently]
irradiated fuel assemblies.
AND C.2.2---------------
NOTE Limited plant cooldown or boron dilution is allowed provided the change is accounted for in the calculated SDM.Suspend positive reactivity additions.
SURVEILLANCE REQUIREMENTS SURVEILLANCE Immediately Immediately FREQUENCY SR 3.3.9.1 Perform a CHANNEL CHECK on the required control room radiation monitor channel.CEOG STS 3.3.9-2 Rev.3.0, 03/31/04 CRlS (Digital)
 
====3.3.9 SURVEILLANCE====
REQUIREMENTS (continued)
SURVEILLANCE SR 3.3.9.2 Perform a CHANNEL FUNCTIONAL TEST on required CRlS radiation monitor channel.
Verify CRlS high radiation setpoint [Allowable Value]
is 2 [6E4] cpm above normal background. SR 3.3.9.3
..............................
NOTES .............................
I. Surveillance of Actuation Logic shall include the verification of the proper operation of each initiation relay.
: 2. Relays associated with plant equipment that cannot be operated during plant operation are required to be tested during each MODE 5 entry exceeding 24 hours unless tested within the previous 6 months. ----------d++----------------+---------------*-----------------+-----
Perform a CHANNEL FUNCTIONAL TEST on required CRlS Actuation Logic channel. SR 3.3.9.4 Perform a CHANNEL CALIBRATION on required CRlS radiation monitor channel.
SR 3.3.9.5 Perform a CHANNEL FUNCTIONAL TEST on required CRlS Manual Trip channel.
SR 3.3.9.6 [ Verify that response time of required CRlS channel is within limits. CEOG STS FREQUENCY - [92] days 4 , - I [18] months 4' d L- '- 2--we+ c T .?",:,,I --- C n - j < 1181 months '?' i Rev. 3.0, 03/31/04 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE CRIS (Digital)3.3.9 FREQUENCY SR 3.3.9.2 SR 3.3.9.3 SR 3.3.9.4 SR 3.3.9.5 SR 3.3.9.6 CEOG STS Perform a CHANNEL FUNCTIONAL TEST on required CRIS radiation monitor channel.Verify CRIS high radiation setpoint[Allowable Value]is::;;[6E4]cpm above normal background.
1.Surveillance of Actuation Logic shall include the verification of the proper operation of each initiation relay.2.Relays associated with plant equipment that cannot be operated during plant operation are reqUired to be tested during each MODE 5 entry exceeding 24 hours unless tested within the previous 6 months.Perform a CHANNEL FUNCTIONAL TEST on required CRIS Actuation Logic channel.Perform a CHANNEL CALIBRATION on required CRIS radiation monitor channel.Perform a CHANNEL FUNCTIONAL TEST on required CRIS Manual Trip channel.[Verify that response time of reqUired CRrS channel is within limits.3.3.9-3 Rev.3.0, 03/31104 FHIS (Digital) 3.3.10 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.10.1 Perform a CHANNEL CHECK on required FHlS E2 hours +,*- radiation monitor channel.
1 [ Airborne Particulate1 Iodine: s [6E4] cpm above background
] SR 3.3.10.2 Perform a CHANNEL FUNCTIONAL TEST on required FHlS radiation monitor channel. Verify radiation monitor setpoint [Allowable Values]: Airborne Gaseous:
5 [6E4] cpm above background
@2 days 4' do,---h + *. -- f 11 Zt:rt 1;) %--- -.-. --. - -. - SR 3.3.10.3 -------------------------------NOTE Testing of Actuation Logic shall include the actuation of each initiation relay and verification of the proper operation of each ignition relay. SR 3.3.10.5 Perform a CHANNEL CALIBRATION on required I fi8] months Perform a CHANNEL FUNCTIONAL TEST on required FHlS Actuation Logic channel.
FHlS radiation monitor channel.
SR 3.3.10.4 Perform a CHANNEL FUNCTIONAL TEST on required FHlS Manual Trip logic. SR 3.3.10.6 within limits. - @8] months ( - CEOG STS Rev. 3.0, 03/31/04 FHIS (Digital)3.3.10 SURVEILLANCE REQUIREMENTS D SURVEILLANCE FREQUENCY SR 3.3.10.1 Perform a CHANNEL CHECK on required FHIS E2 hoursradiation monitor channel.rD\-_**_*__*******Ir\Sert., SR 3.3.10.2 Perform a CHANNEL FUNCTIONAL TEST on@2days required FHIS radiation monitor channel.Verify****r radiation monitor setpoint[Allowable Values]: 'I.\t
,,----,-......
__...[Airborne Particulate/Iodine:
::;[6E4]cpm above background]
Airborne Gaseous:::;[6E4]cpm above background SR 3.3.10.3------------*****-*------------NOTE-------------------.----------
Testing of Actuation Logic shall include the actuation of each initiation relay and verification of the proper operation of each ignition relay.---------------------_
......._------------------_
.._...----------------------
Perform a CHANNEL FUNCTIONAL TEST on ill 8]months 4:*,,""'\required FHIS Actuation Logic channel.
SR 3.3.10A Perform a CHANNEL FUNCTIONAL TEST on ill 8]months<eo....required FHIS Manual Trip logic.\.
InSF'T SR 3.3.10.5 Perform a CHANNEL CALIBRATION on requiredmonths FHIS radiation monitor channel.6::---"'';;;:''''-
__..
.
..
..".!:,.,.iliS]
____SR 3.3.10.6[Verify response time of required FHIS channel is within limits.IYfr.rt.--CEOG STS 3.3.10-2 Rev.3.0, 03/31/04 PAM Instrumentation (Digital) 3.3.1 1 ACTIONS (continued)
CONDITION E. As required by Required Action D.l and referenced in Table 3.3.1 1-1. F. [ As required by Required Action D.l and referenced in Table 3.3.1 1-1. REQUIRED ACTION E.l Be in MODE 3. AND E.2 Be in MODE 4. F.l Initiate action in accordance with Specification
 
====5.6.5. COMPLETION====
TIME 6 hours 12 hours Immediately
] SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.11.1 Perform CHANNEL CHECK for each required instrumentation channel that is normally energized.
SR 3.3.11.2 ...............................
NOTE------------------------------
Neutron detectors are excluded from the CHANNEL CALIBRATION. Perform CHANNEL CALIBRATION.
CEOG STS Rev. 3.1, 12/01/05 PAM Instrumentation (Digital)3.3.11 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME E.As required by Required E.1 Be in MODE 3.6 hours Action 0.1 and referenced in AND Table 3.3.11-1.E.2 Be in MODE 4.12 hours F.[As required by F.1Initiateaction in accordance Immediately]
Required Action 0.1 and with Specification 5.6.5.referenced in Table 3.3.11-1.SURVEILLANCE REQUIREMENTS
------------------------------------------------------------
NOT E These SRs apply to each PAM instrumentation Function in Table 3.3.11-1.SR 3.3.11.1 SR 3.3.11.2 CEOG STS SURVEILLANCE Perform CHANNEL CHECK for each required instrumentation channel that is normally energized.
-------------------------------NOTE------------------------------
Neutron detectors are excluded from the CHANNEL CALIBRATION.
Perform CHANNEL CALIBRATION.
3.3.11-2 FREQUENCY[08]months<_'\Rev.3.1,12/01/05 Remote Shutdown System (Digital) 3.3.12 3.3 INSTRUMENTATION 3.3.12 Remote Shutdown System (Digital)
LC0 3.3.12 The Remote Shutdown System Functions shall be OPERABLE, APPLICABILITY: MODES 1, 2, and 3. CONDITION A. One or more required Functions inoperable.
B. Required Action and associated Completion Time not met. REQUIRED ACTION A.l Restore required Functions to OPERABLE status.
B.l Be in MODE 3. AND B.2 Be in MODE 4. COMPLETION TIME 30 days 6 hours [I 21 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE
[ Perform CHANNEL CHECK for each required instrumentation channel that is normally energized.
SR 3.3.12.2 Verify each required control circuit and transfer switch is capable of performing the intended function. CEOG STS FREQUENCY Rev. 3.0, 03/31/04 Remote Shutdown System (Digital)3.3.12 3.3 INSTRUMENTATION 3.3.12 Remote Shutdown System (Digital)LCO 3.3.12 APPLICABILITY:
The Remote Shutdown System Functions shall be OPERABLE.MODES 1, 2, and 3.ACTIONS Separate Condition entry is allowed for each Function.CONDITION REQUIRED ACTION COMPLETION TIME A.One or more required A.1 Restore required Functions 30 days Functions inoperable.
to OPERABLE status.B.Required Action and B.1 Be in MODE 3.6 hours associated Completion Time not met.AND B.2 Be in MODE 4.[12]hours SURVEILLANCE REQUIREMENTS SR 3.3.12.1 SR 3.3.12.2 CEOG STS SURVEILLANCE
[Perform CHANNEL CHECK for each required instrumentation channel that is normally energized.
Verify each required control circuit and transfer switch is capable of performing the intended function.3.3.12-1 FREQUENCY Rev.3.0, 03/31/04/I Remote Shutdown System (Digital) 3.3.12 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE SR 3.3.12.3 ...............................
NOTE .............................. Neutron detectors are excluded from the CHANNEL CALIBRATION.
.................................................................... Perform CHANNEL CALIBRATION for each required instrumentation channel.
SR 3.3.12.4 [ Perform CHANNEL FUNCTIONAL TEST of the reactor trip circuit breaker openlclosed indication.
FREQUENCY - [I81 months 6-., -k.. F8 months 1 1 CEOG STS Rev. 3.0, 03/31/04 Remote Shutdown System (Digital)3.3.12 SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.12.3 SR 3.3.12.4 CEOG STS SURVEILLANCE0TE------------------------------
Neutron detectors are excluded from the CHANNEL CALIBRATION.
Perform CHANNEL CALIBRATION for each required instrumentation channel.[Perform CHANNEL FUNCTIONAL TEST of the reactor trip circuit breaker open/closed indication.
3.3.12-2 FREQUENCY Rev.3.0, 03/31/04
[Logarithmic]
Power Monitoring Channels (Digital) 3.3.1 3 SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.3.13.1 Perform CHANNEL CHECK. SR 3.3.13.2 Perform CHANNEL FUNCTIONAL TEST.
Perform CHANNEL CALIBRATION.
FREQUENCY
[92] days i, +.-" [18] months -. X- - (~~~rt CEOG STS Rev. 3.0, 03131104 [Logarithmic]
Power Monitoring Channels (Digital)3.3.13 SURVEILLANCE REQUIREMENTS SR 3.3.13.1 SR 3.3.13.2 SR 3.3.13.3 CEOG STS SURVEILLANCE Perform CHANNEL CHECK.Perform CHANNEL FUNCTIONAL TEST.------------------------------
NOT E------------------------------
Neutron detectors are excluded from CHANNEL CALIBRATION.
Perform CHANNEL CALIBRATION.
3.3.13-2 FREQUENCY Rev.3.0, 03/31/04 RCS Pressure, Temperature, and Flow [DNB] Limits
 
====3.4.1 ACTIONS====
(continued)
CONDITION REQUIRED ACTION COMPLETION TIME C. RCS cold leg C.1 Restore cold leg 2 hours temperature not within temperature to within limits. limits. D. Required Action and 1 Reduce THERMAL 6 hours associated Completion POWER to 5 [30]% RTP. Time of Condition C not met. SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.4.1.1 Verify pressurizer pressure 2 [2025] psia and I [2275] psia. SR 3.4.1.2 Verify RCS cold leg temperature 2 [535I0F and I [558J&deg;F for 1701% RTP or 2 [544I0F and I [558IoF for 2 [70]% RTP. SR 3.4.1.3 -------------"+--------------*-
NOTE .............................. Only required to be met in MODE I. Verify RCS total flow rate 2 [I48 E6] Iblhour. SR 3.4.1.4 -----+-------------------------
NOTE .............................. Not required to be performed until
[24] hours after 2 [go]% RTP. Verify by precision heat balance that RCS total flow rate within limits specified in the COLR. FREQUENCY n2 hours &, @8] months h CEOG STS Rev. 3.0, 03/31/04 RCS Pressure, Temperature, and Flow[DNB]Limits 3.4.1 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME C.RCS cold leg C.1 Restore cold leg 2 hours temperature not within temperature to within limits.limits.D.Required Action and 0.1" Reduce THERMAL 6 hours associated Completion POWER to:::;[30]%RTP.Time of Condition C not met.SURVEILLANCE REQUIREMENTS SR 3.4.1.1 SR 3.4.1.2 SR 3.4.1.3 SR 3.4.1.4 CEOG STS SURVEILLANCE Verify pressurizer pressure 2::[2025]psia and:::;[2275]psia.Verify RCS cold leg temperature 2::[535]OF and:::;f558jOF for<170J%RTP or 2::[544]OF and:::;[558]OF for?:[70]%RTP.
NOT E------------------------------
Only required to be met in MODE 1.Verify ReS total flow rate 2::[148 E6]Ib/hour.-------------------------------
NOTE------------------------------
Not required to be performed until[24]hours after?:[90]%RTP.Verify by precision heat balance that RCS total flow rate within limits specified in the COLR.3.4.1-2 FREQUENCY[12 hours\..[12 hoursk-(/.
I h 5ettD[[18]months crnsertp Rev.3.0, 03/31/04 RCS Minimum Temperature for Criticality 3.4.2 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.2 RCS Minimum Temperature for Criticality LC0 3.4.2 Each RCS loop average temperature (T,,) shall be 2 [520I0F. APPLICABILITY: MODE 1 with T,,, in one or more RCS loops
< [535I0F, MODE 2 with Tavg in one or more RCS loops
< [535J&deg;F and Ketr 2 1 .O. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY
-- A. T,,, in one or more RCS loops not within limit.
SR 3.4.2.1 Verify RCS T,,, in each loop 2 [520I0F. CEOG STS A.1 Be in MODE 2 with Kerf < 1 .O. Rev. 3.0, 03/31/04 - - 30 minutes RCS Minimum Temperature for Criticality 3.4.2 3.4 REACTOR COOLANT SYSTEM (RCS)3.4.2 RCS Minimum Temperature for Criticality LCO 3.4.2 Each RCS loop average temperature (T avg)shall be:::::[520JoF.APPLICABILITY:
ACTIONS MODE 1 with T avg in one or more RCS loops<[535]OF, MODE 2 with T avg in one or more RCS loops<[535jOF and K eff 2:: 1.0.CONDITION A.T avg in one or more RCS A.1 loops not within limit.SURVEILLANCE REQUIREMENTS REQUIRED ACTION Be in MODE 2 with K eff<1.0.COMPLETION TIME 30 minutes SR 3.4.2.1 CEOG STS SURVEILLANCE Verify RCS T avg in each loop:::::[520]OF.3.4.2-1 FREQUENCY Rev.3.0, 03/31/04 RCS P/T Limits 3.4.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY CEOG STS Verify RCS pressure, RCS temperature, and RCS heatup and cooldown rates within limits specified in the PTLR. Rev. 3.0, 03/31/04 EO SURVEILLANCE REQUIREMENTS SURVEILLANCE RCS PIT Limits 3.4.3 FREQUENCY SR 3.4.3.1 CEOG STS------------------------------NOTE------------------------------
Only required to be performed during RCS heatup and cool down operations and RCS inservice leak and hydrostatic testing.Verify RCS pressure, RCS temperature, and RCS heatup and cooldown rates within limits specified in the PTLR.3.4.3-2 Rev.3.0, 03/31/04 RCS Loops - MODES 1 and 2 3.4.4 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.4 RCS Loops - MODES 1 and 2 LC0 3.4.4 Two RCS loops shall be OPERABLE and in operation.
APPLICABILITY:
MODES I and 2. ACTIONS A. Requirements of LC0 not met. A.l Be in MODE 3. 6 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE I FREQUENCY CEOG STS Rev. 3.0, 03/31/04 RCS Loops-MODES 1 and 2 3.4.4 3.4 REACTOR COOLANT SYSTEM (RCS)3.4.4 RCS Loops-MODES 1 and 2 LCO 3.4.4 Two RCS loops shall be OPERABLE and in operation.
APPLICABILITY:
ACTIONS MODES 1 and 2.CONDITION A.Requirements of LCO not met.A.1 REQUIRED ACTION Be in MODE 3.COMPLETION TIME 6 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.4.1 CEOG STS Verify each RCS loop is in operation.
3.4.4-1 Rev.3.0.03/31/04 RCS Loops - MODE 3 3.4.5 ACTIONS (continued)
CONDITION REQUIRED ACTION I COMPLETION TIME SURVEILLANCE REQUIREMENTS C.2 Initiate action to restore one RCS loop to OPERABLE status and operation.
SURVEILLANCE I FREQUENCY Immediately E2 hours ,$-.-* SR 3.4.5.1 Verify one RCS loop is in operation.
SR 3.4.5.2 Verify secondary side water level in each steam @ hours 4.- generator 2 [25]%. SR 3.4.5.3 ---------+++-------------------NOTE
..............................
Not required to be performed until 24 hours after a required pump is not in operation. Verify correct breaker alignment and indicated power available to each required pump. CEOG STS Rev. 3.0, 03/31/04 RCS Loops-MODE 3 3.4.5 ACTIONS (continued)
CONDITION REQUIRED ACTION C.2 Initiate action to restore one RCS loop to OPERABLE status and operation.
SURVEILLANCE REQUIREMENTS SURVEILLANCE COMPLETION TIME Immediately FREQUENCY SR 3.4.5.1 SR 3.4.5.2 SR 3.4.5.3 CEOG STS Verify one RCS loop is in operation.
Verify secondary side water level in each steam generator;::::
[25]%.
Not required to be performed until 24 hours after a required pump is not in operation.
Verify correct breaker alignment and indicated power available to each required pump.3.4.5-2\1..days (--'-._-,'\.
Cr..r\5erfD Rev.3.0, 03/31/04 RCS Loops - MODE 4 3.4.6 ACTIONS (continued)
CONDITION B. Two required loops or trains inoperable. Required loop or train not in operation. REQUIRED ACTION B.l Suspend operations that would cause introduction of coolant into the RCS with boron concentration less than required to meet SDM of LC0 3.1 .I. B.2 Initiate action to restore one loop or train to OPERABLE status and operation.
COMPLETION TIME 24 hours SURVEILLANCE REQUIREMENTS - P. SURVEILLANCE Immediately Immediately - SR 3.4.6.1 Verify required RCS loop or SDC train is in operation.
SR 3.4.6.2 Verify secondary side water level in required SG(s) is 2 [25]%. SR 3.4.6.3 -------------------------------NOTE
--------------------------+-+-
Not required to be performed until 24 hours after a required pump is not in operation.
..................................................................... Verify correct breaker alignment and indicated power available to each required pump.
CEOG STS FREQUENCY hours hours +yi Rev. 3.0, 03/31/04 RCS Loops-MODE 4 3.4.6 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME A.2---------------
NOTE--------------
Only required to be met if SOC train is OPERABLE.-------------------------------------
Be in MODE 5.'24 hours B.Two required loops or B.1 Suspend operations that Immediately trains inoperable.
would cause introduction of coolant into the RCS with OR boron concentration less than required to meet SDM Required loop or train of LCO 3.1.1.not in operation.
AND B.2 Initiate action to restore one Immediately loop or train to OPERABLE status and operation.
SURVEILLANCE REQUIREMENTS SR 3.4.6.1 SR 3.4.6.2 SR 3.4.6.3 CEOG STS SURVEILLANCE Verify required RCS loop or SOC train is in operation.
Verify secondary side water level in required SG(s)is::::[25]%.-------------------------------
NOT E----------------------------+-
Not required to be performed until 24 hours after a required pump is not in operation.
Verify correct breaker alignment and indicated power available to each required pump.3.4.6-2 FREQUENCY@hours(:Cn5e.({lJ E.days It:-"\
___(Insrti)Rev.3.0, 03/31/04 RCS Loops - MODE 5, Loops Filled
 
====3.4.7 SURVEILLANCE====
REQUIREMENTS SURVEILLANCE SR 3.4.7.1 Verify required SDC train is in operation.
SR 3.4.7.2 Verify required SG secondary side water level is 2 [25]%. SR 3.4.7.3 -------------------------------NOTE
-----------+------------------
Not required to be performed until 24 hours after a required pump is not in operation.
-----------------*----------------------++----------------------*---- Verify correct breaker alignment and indicated power available to each required SDC pump. FREQUENCY c2 hours +,.., CEOG STS Rev. 3.0, 03/31/04 RCS Loops-MODE 5, Loops Filled 3.4.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.7.1 Verify required SOC train is in operation.
E2
(_____---r-__
SR 3.4.7.2 SR 3.4.7.3 CEOG STS Verify required SG secondary side water level is<::[25]%.
NOT E------------------------------
Not required to be performed until 24 hours after a required pump is not in operation.
Verify correct breaker alignment and indicated power available to each required SOC pump.3.4.7-3 IT 2 hours__..Rev.3.0, 03/31/04 ACTIONS (continued)
CONDITION B. No required SDC train OPERABLE.
OR - Required SDC train not in operation. RCS Loops - MODE 5, Loops Not Filled
 
====3.4.8 REQUIRED====
ACTION Suspend operations that would cause introduction of coolant into the RCS with boron concentration less than required to meet SDM of LC0 3.1.1. Initiate action to restore one SDC train to OPERABLE status and operation.
COMPLETION TIME Immediately lmmediately SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.4.8.1 Verify required SDC train is in operation.
SR 3.4.8.2 --------------------------+**--
NOTE .............................. Not required to be petformed until 24 hours after a required pump is not in operation.
--------------------*-+----------------------------------------------
Verify correct breaker alignment and indicated power available to each required SDC pump. CEOG STS - - FREQUENCY 4 7 days ee' -1 4 *"; -*-. ".""$- 6 i -.:.1 - **--- *. . ---d Rev. 3.0, 03/31/04 RCS Loops-MODE 5.Loops Not Filled 3.4.8 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME B.No required SDC train B.1 Suspend operations that Immediately OPERABLE.would cause introduction of coolant into the RCS with OR boron concentration less than required to meet SDM Required SDC train not ofLC03.1.1.
in operation.
AND B.2Initiateaction to restore Immediately one SDC train to OPERABLE status and operation.
SURVEILLANCE REQUIREMENTS SR 3.4.8.1 SR 3.4.8.2 CEOG STS SURVEILLANCE Verify required SDC train is in operation.
NOTE------------------------------
Not required to be performed until 24 hours after a required pump is not in operation.
Verify correct breaker alignment and indicated power available to each required SDC pump.3.4.8-2 FREQUENCY Rev.3.0, 03/31/04 Pressurizer
 
====3.4.9 SURVEILLANCE====
REQUIREMENTS SURVEILLANCE SR 3.4.9.1 Verify pressurizer water level is < [60]%. -----------*----------------------
REVIEWER'S NOTE -a*------------------------------ The frequency for performing pressurizer heater capacity testing shall be either 18 months or 92 days, depending on whether or not the plant has dedicated safety-related heaters. For dedicated safety-related heaters, which do not normally operate, 92 days is applied. For non- dedicated safety-related heaters, which normally operate, 18 months is applied. --d--**-w-v-----------------------------------------------------------------+-+-+-------v------
SR 3.4.9.2 Verify capacity of each required group of pressurizer heaters 2 [I 501 kW. SR 3.4.9.3 [ Verify required pressurizer heaters are capable of being powered from an emergency power supply. FREQUENCY i [18] months 4 - : ![{8] months "7 ] CEOG STS Rev. 3.0, 03/31/04 SURVEILLANCE REQUIREMENTS SURVEILLANCE Pressurizer
 
====3.4.9 FREQUENCY====
SR 3.4.9.1 Verify pressurizer water level is<[60]%.---------*------------------------REVI EWE R'S NOTE---------------------------------
The frequency for performing pressurizer heater capacity testing shall be either 18 months or 92 days, depending on whether or not the plant has dedicated safety-related heaters.For dedicated safety-related heaters, which do not normally operate, 92 days is applied.Fordedicated safety-related heaters, which normally operate, 18 months is applied.SR 3.4.9.2 SR 3.4.9.3 CEOG STS Verify capacity of each required group of pressurizer heaters;:::
[150]kW.[Verify required pressurizer heaters are capable of being powered from an emergency power supply.3.4.9-2 Rev.3.0, 03/31/04 SURVEILLANCE REQUIREMENTS SURVEILLANCE Pressurizer PORVs 3.4.11 FREQUENCY SR 3.4.11.1 SR 3.4.11.2---------------
---------------
N OT ES--------
--------------.------
1.Not required to be performed with block valve closed in accordance with the Required Actions of this LCO.2.Only required to be performed in MODES 1 and 2.Perform a complete cycle of each block valve.-------------------------------
NOTE------------------------------
Only required to be performed in MODES 1 and 2.
Perform a complete cycle of each PORV.(118]months SR 3.4.11.3 SR 3.4.11.4 CEOG STS[Perform a complete cycle of each solenoid air control valve and check valve on the air accumulators in PORV control systems.[Verify PORVs and block valve(s)are capable of being powered from an emergency power supply.3.4.11-3@8]
Rev.3.0, 03/31/04 LTOP System 3.4.12 ACTIONS (continued)
CONDITION G. Two required PORVs inoperable. Required Action and associated Completion Time of Condition A, [B], Dl El or F not met, LTOP System inoperable for any reason other than Condition A, [B], C, Dl E, or F. REQUIRED ACTION G. 1 Depressurize RCS and establish RCS vent of z [I .3] square inches. COMPLETION TIME 12 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.12.1 Verify a maximum of one HPSl pump is capable of injecting into the RCS. SR 3.4.12.2 Verify a maximum of one charging pump is capable of injecting into the RCS. SR 3.4.12.3 Verify each SIT is isolated.
SR 3.4.12.4 Verify required RCS vent 2 [I .3] square inches is 62 hours for open. unlocked open vent valve(s) CEOG STS Rev. 3.0, 03/31/04 LTOPSystem 3.4.12 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME G.Two required PORVs inoperable.
G.1 Depressurize RCS and , establish RCS vent of[1.3]square inches, 12 hours Required Action and associated Completion Time of Condition A,[8], D, E, or F not met.LTOP System inoperable for any reason other than Condition A,[8], C, 0, E, or F.SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.12.1 Verify a maximum of one HPSI pump is capable of injecting into the RCS.1I2hours Q V IYlserf:t SR 3.4.12.2 Verify a maximum of one charging pump is capable of injecting into the RCS.SR 3.4.12.3 SR 3.4.12.4 Verify each SIT is isolated.Verify required RCS vent[1.3]square inches is open.(i2 G2 hours for unlocked open vent valve(s)3.4.12-3 CEOG STS AND 31 days for othervent path(s)Co,.......l-r i::j (L
, Rev.3.0, 03/31/04 LTOP System 3.4.12 SURVEILLANCE REQUIREMENTS (continued)
SR 3.4.12.6 ------------------------------NOTE
..............................
Not required to be performed until [I21 hours after decreasing RCS cold leg temperature to less than or equal to the LTOP enable temperature specified in the PTLR. -------------**-*-----------------------------------*----------------
SURVEILLANCE SR 3.4.12.5 Verify PORV block valve is open for each required PORV. FREQUENCY E2 hours cmtg SR 3.4.12.7 Perform CHANNEL CALIBRATION on each Ifiiis] months 4. , .G Perform CHANNEL FUNCTIONAL TEST on each required PORV, excluding actuation.
required PORV actuation channel.
El days +--,. C5 5e.t I> CEOG STS Rev. 3.0, 03/31/04 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE LTOP System 3.4.12 FREQUENCY SR 3.4.12.5 SR 3.4.12.6 SR 3.4.12.7 CEOG STS Verify PORV block valve is open for each required PORV.------------------------------N0TE------------------------------
Not required to be performed until[12]hours after decreasing RCS cold leg temperature to less than or equal to the L TOP enable temperature specified in the PTLR.Perform CHANNEL FUNCTIONAL TEST on each required PORV, excluding actuation.
Perform CHANNEL CALIBRATION on each required PORV actuation channel.3.4.12-4 111 days....(,,-.L........*-,'::e-.*-
*-rt........:t-:;*Rev.3.0, 03/31/04 RCS Operational LEAKAGE 3.4.13 SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.4.13.1 ..............................
NOTES .............................
I. Not required to be performed until 12 hours after establishment of steady state operation.
Verify RCS operational LEAKAGE is within limits by performance of RCS water inventory balance.
SR 3.4.13.2 -------------------------------NOTE
..............................
Not required to be performed until 12 hours after establishment of steady state operation.
.....................................................................
Verify primary to secondary LEAKAGE is I 150 gallons per day through any one SG. CEOG STS FREQUENCY k2 hours Rev. 3.1, 12/01/05 RCS Operational LEAKAGE 3.4.13 SURVEILLANCE REQUIREMENTS SR 3.4.13.1 SR 3.4.13.2 CEOG STS SURVEILLANCE
------------------------------NOTES-----------------------------
1.Not required to be performed until 12 hours after establishment of steady state operation.
2.Not applicable to primary to secondary LEAKAGE.Verify RCS operational LEAKAGE is within limits by performance of RCS water inventory balance.-------------------------------
NOTE------------------------------
Not required to be performed until 12 hours after establishment of steady state operation.
Verify primary to secondary LEAKAGE is S 150 gallons per day through anyone SG.3.4.13-2 FREQUENCY"r---__.(Lnsertl)l1.2 hours(In.serf iJ Rev.3.1,12/01/05 SURVEILLANCE REQUIREMENTS SURVEILLANCE RCS PIV Leakage 3.4.14 FREQUENCY SR 3.4.14.1 CEOG STS------------------------------
NOTES----------------------------
1.Not required to be performed in MODES 3 and 4.2.Not required to be performed on the RCS PIVs located in the SDC flow path when in the shutdown cooling mode of operation.
3.RCS PIVs actuated during the performance of this Surveillance are not required to be tested more than once if a repetitive testing loop cannot be avoided.Verify leakage from each RCS PIV is equivalent to::;0.5 gpm per nominal inch of valve size up to a maximum of 5 gpm at an RCS pressure[2215]psia and::;[2255]psia.3.4.14-3 In accordance with the InserVice Testing Program, AND Prior to entering MODE 2 determine the unit has been in MODE 5 for 7 days or more, if leakage testing has not been performed in the previous 9 months Within 24 hours following valve actuation due to automatic or manual action or flow through the valve Rev.3.0, 03/31/04 SURVEILLANCE REQUIREMENTS SURVEILLANCE RCS PIV Leakage 3.4.14 FREQUENCY SR 3.4.14.1 CEOG STS------------------------------
NOTES----------------------------
1.Not required to be performed in MODES 3 and 4.2.Not required to be performed on the RCS PIVs located in the SDC flow path when in the shutdown cooling mode of operation.
3.RCS PIVs actuated during the performance of this Surveillance are not required to be tested more than once if a repetitive testing loop cannot be avoided.Verify leakage from each RCS PIV is equivalent to::;0.5 gpm per nominal inch of valve size up to a maximum of 5 gpm at an RCS pressure[2215]psia and::;[2255]psia.3.4.14-3 In accordance with the Inserl/ice
.Testing Program, an<{[18)
AND Prior to entering MODE 2 determine the unit has been in MODE 5 for 7 days or more, if leakage testing has not been performed in the previous 9 months Within 24 hours following valve actuation due to automatic or manual action or flow through the valve Rev.3.0, 03/31/04 RCS PIV Leakage 3.4.14 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE
.- - SR 3.4.14.2 ...............................
NOTE ..............................
[ Not required to be met when the SDC System autoclosure interlock is disabled in accordance with SR 3.4.12.7. Verify SDC System autoclosure interlock prevents the valves from being opened with a simulated or actual RCS pressure signal r [425] psig. SR 3.4.14.3 -------------------------------NOTE
---------------------------dm-
[ Not required to be met when the SDC System autoclosure interlock is disabled in accordance with SR 3.4.12.7.
Verify SDC System autoclosure interlock causes the valves to close automatically with a simulated or actual RCS pressure signal 2 [600] psig. CEOG STS FREQUENCY 4 4 [ls] months ] ) - Rev. 3.0, 03/31/04 SURVEILLANCE RCS PIV Leakage 3.4.14 FREQUENCY SR 3.4.14.2 SR 3.4.14.3 CEOG STS-------------------------------NOTE------------------------------
[Not required to be met when the SOC System autoclosure interlock is disabled in accordance with SR 3.4.12.7.Verify SOC System autoclosure interlock prevents the valves from being opened with a simulated or actual RCS pressure signal[425]psig.-------------------------------
NOT E------------------------------
[Not required to be met when the SOC System autoclosure interlock is disabled in accordance with SR 3.4.12.7.Verify SOC System autoclosure interlock causes the valves to close automatically with a simulated or actual RCS pressure signal[600]psig.3.4.14-4 Rev.3.0, 03/31104 RCS Leakage Detection Instrumentation ACTIONS (continued)
CONDITION D. [ Required containment atmosphere radioactivity monitor inoperable. Required containment air cooler condensate flow rate monitor inoperable.
E. Required Action and associated Completion Time not met.
F. All required monitors inoperable. REQUIRED ACTION D.l Restorerequired containment atmosphere radioactivity monitor to OPERABLE status. D.2 Restore required containment air cooler condensate flow rate monitor to OPERABLE status. E.1 Be in MODE 3. @ E.2 Be in MODE 5. F.l Enter LC0 3.0.3. COMPLETION TIME 30 days 30 days 6 hours 36 hours Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.15.1 Perform CHANNEL CHECK of the required
@] hours f7 containment atmosphere radioactivity monitor. (h~cr t l) . SR 3.4.15.2 Perform CHANNEL FUNCTIONAL TEST of the E2 days + required containment atmosphere radioactivity monitor. SR 3.4.15.3 Perform CHANNEL CALIBRATION of the required @8] months- containment sump monitor.
t 31 CEOG STS 3.4.15-3 Rev. 3.0, 03/31/04 RCS Leakage Detection Instrumentation 3.4.15 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME D.[Required containment D.1 Restore required 30 days atmosphere radioactivity containment atmosphere monitor inoperable.
radioactivity monitor to OPERABLE status.AND OR Required containment air cooler condensate D.2 Restore required 30 days]flow rate monitor containment air cooler inoperable.
condensate flow rate monitor to OPERABLE status.E.Required Action and E.1 Be in MODE 3.6 hours associated Completion Time not met.AND E.2 Be in MODE 5.36 hours F.All required monitors F.1 Enter LCO 3.0.3.Immediately inoperable.
SURVEILLANCE REQUIREMENTS SR 3.4.15.1 SR 3.4.15.2 SR 3.4.15.3 CEOG STS SURVEILLANCE Perform CHANNEL CHECK of the required containment atmosphere radioactivity monitor.Perform CHANNEL FUNCTIONAL TEST of the required containment atmosphere radioactivity monitor.Perform CHANNEL CALIBRATION of the required containment sump monitor.3.4.15-3 FREQUENCY@2]hours i) fIn:-.erf 1)Rev.3.0, 03/31/04 RCS Leakage Detection Instrumentation 3.4.15 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE SR 3.4.15.4 Perform CHANNEL CALIBRATION of the required containment atmosphere radioactivity monitor. CEOG STS FREQUENCY
@8) months \ en~erk 13 SR 3.4.15.5 [ Perform CHANNEL CALIBRATION of the required containment air cooler condensate flow rate monitor.
Rev. 3.0. 03/31/04 p8] mont RCS Leakage Detection Instrumentation 3.4.15 SURVEILLANCE REQUIREMENTS (continued)
SR 3.4.15.4 SR 3.4.15.5 CEOG STS SURVEILLANCE Perform CHANNEL CALIBRATION of the required containment atmosphere radioactivity monitor.(Perform CHANNEL CALIBRATION of the required containment air cooler condensate flow rate monitor.3.4.15-4 FREQUENCY 112 8}months(In5erl.1 J Rev.3.0, 03/31104 RCS Specific Activity ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME C. Gross specific activity of C.l Be in MODE 3 with the reactor coolant not T,, < 500&deg;F. within limit.
6 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE Verify reactor coolant gross specific activity
< lOO/E pCi/gm. SR 3.4.16.2 ...............................
NOTE .............................. Only required to be performed in MODE 1. Verify reactor coolant DOSE EQUIVALENT 1-131 specific activity 5 I .O pCi/gm. SR 3.4.16.3
...............................
NOTE------------------------------
Not required to be performed until 31 days after a minimum of 2 EFPD and 20 days of MODE 1 operation have elapsed since the reactor was last subcritical for 2 48 hours. Determine E from a sample taken in MODE 1 after a minimum of 2 EFPD and 20 days of MODE 1 operation have elapsed since the reactor was last subcritical for Z 48 hours. FREQUENCY 7 days d 14 days - -+, AND Between 2 and 6 hours after THERMAL POWER change of 2 15% RTP within a 1 hour period CEOG STS 3.4.16-2 Rev. 3.0, 03/31/04 RCS Specific Activity 3.4.16 ACTIONS (continued)
CONDITION C.Gross specific activity of C.1 the reactor coolant not within limit.SURVEILLANCE REQUIREMENTS REQUIRED ACTION Be in MODE 3 with T avg<500&deg;F.COMPLETION TIME 6 hours SR 3.4.16.1 SR 3.4.16.2 SR 3.4.16.3 CEOG STS SURVEILLANCE Verify reactor coolant gross specific activity:s;100/E flCi/gm.-------------------------------
NOT E------------------------------
Only required to be performed in MODE 1.Verify reactor coolant DOSE EQUIVALENT 1-131 specific activity:s;1.0 flCi/gm.-------------------------------
NOT E------------------------------
Not required to be performed until 31 days after a minimum of 2 EFPD and 20 days of MODE 1 operation have elapsed since the reactor was last subcritical for48 hours.Determine E from a sample taken in MODE 1 after a minimum of 2 EFPD and 20 days of MODE 1 operation have elapsed since the reactor was last subcritical for 2 48 hours.3.4.16-2 FREQUENCY
(&#xa3;-001-:1) 1I4 days AND Between 2 and6 hours after THERMAL POWER change of15%RTP within a 1 hour period&sect;4dayS Rev.3.0, 03/31/04
 
===3.4 REACTOR===
COOLANT SYSTEM (RCS) 3.4.1 7 Special Test Exception (STE)-RCS Loops LC0 3.4.17 The requirements of LC0 3.4.4, "RCS Loops - MODES I and 2," and the listed requirements of LC0 3.3.1, "Reactor Protective System (RPS)
Instrumentation - Operating," for the [(Analog)
RC flow low, thermal margin or low pressure, and asymmetric steam generator transient protective trip functions] [(Digital) high log power, high local power density, low departure from nucleate boiling ratio protective trip functions]
may be suspended provided:
: a. THERMAL POWER I 5% RTP and b. The reactor trip setpoints of the OPERABLE power level channels are set 5 20% RTP. APPLICABILITY:
MODE 2, during startup and PHYSICS TESTS.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME within limit. SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.4.17.1 Verify THERMAL POWER 15% RTP. SR 3.4.17.2 Perform a CHANNEL FUNCTIONAL TEST on each logarithmic power level and linear power level neutron flux monitoring channel. FREQUENCY 12 hours prior to initiating startup or PHYSICS TESTS CEOG STS Rev. 3.0, 03/31/04 STE-RCS Loops 3.4.17 3.4 REACTOR COOLANT SYSTEM (RCS)3.4.17 Special Test Exception (STE)-RCS Loops LCO 3.4.17 APPLICABILITY:
ACTIONS The requirements of LCO 3.4.4,"RCS Loops-MODES 1 and 2," and the listed requirements of LCO 3.3.1,"Reactor Protective System (RPS)Instrumentation
-Operating," for the[(Analog)RC flow low, thermal margin or low pressure, and asymmetric steam generator transient protective trip functions][(Digital)high log power, high local power density, low departure from nucleate boiling ratio protective trip functions) may be suspended provided: a.THERMAL POWER5%RTP and b.The reactor trip setpoints of the OPERABLE power level channels are set20%RTP.MODE 2, during startup and PHYSICS TESTS.CONDITION A.THERMAL POWER not A.1 within limit.SURVEILLANCE REQUIREMENTS REQUIRED ACTION Open reactor trip breakers.COMPLETION TIME Immediately SR 3.4.17.1 SR 3.4.17.2 CEOG STS SURVEILLANCE Verify THERMAL POWER5%RTP.Perform a CHANNEL FUNCTIONAL TEST on each logarithmic power level and linear power level neutron flux monitoring channel.3.4.17-1 FREQUENCY["hour t.1)12 hours prior to initiating startup or PHYSICS TESTS Rev.3.0, 03/31/04 SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.5.1.1 Verify each SIT isolation valve is fully open. SR 3.5.1.2 Verify borated water volume in each SIT is 2 [28% narrow range (1802 cubic feet) and 2 72% narrow range (1914 cubic feet)]. SR 3.5.1.3 Verify nitrogen cover pressure in each SIT is r [615] psig and I [655] psig. SR 3.5.1.4 Verify boron concentration in each SIT is 2 [I5001 ppm and 5 [2800] ppm. SR 3.5.1.5 Verify power is removed from each SIT isolation valve operator when pressurizer pressure is 2 [2000] psia. FREQUENCY I- &- 12 hours --h--.....- - - (~6tl-rn - - - - - - - - NOTE -------- Only required to be performed for affected SIT Once within 6 hours after each solution volume increase of 2 [I]% of tank volume that is not the result of addition from the refueling water tank CEOG STS Rev. 3.0, 03/31/04 SURVEILLANCE REQUIREMENTS SURVEILLANCE SITs 3.5.1 FREQUENCY SR 3.5.1.1 SR 3.5.1.2 SR 3.5.1.3 SR 3.5.1.4 SR 3.5.1.5 CEOG STS Verify each SIT isolation valve is fully open.Verify borated water volume in each SIT is;:::[28%narrow range (1802 cubic feet)and72%narrow range (1914 cubic feet)].Verify nitrogen cover pressure in each SIT is;:::[615]psig and[655]psig.Verify boron concentration in each SIT is;:::[1500]ppm and[2800]ppm.Verify power is removed from each SIT isolation valve operator when pressurizer pressure is::::[2000]psia.3.5.1-2 r:;-k-''\2 hours LlSert i.J@hours li1 days AND',,:__--------N 0 TE--------Only required to be performed for affected SIT Once within 6 hours after each solution volume increase of::::[1]%of tank volume that is not the result of addition from the refueling water tank Rev.3.0, 03/31/04 ECCS - Operating
 
====3.5.2 ACTIONS====
(continued)
CONDITION D. Less than 100% of the ECCS flow equivalent to a single OPERABLE train available. REQUIRED ACTION COMPLETION TIME D.l Enter LC0 3.0.3. Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.5.2.1 [ Verify the following valves are in the listed position with power to the valve operator removed [and key locked in position]. Valve Number Position Function
[ 1 [ 1 tl SR 3.5.2.2 Verify each ECCS 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.
SR 3.5.2.3 [ Verify ECCS piping is full of water. SR 3.5.2.4 Verify each ECCS pump's developed head at the test flow point is greater than or equal to the required developed head. SR 3.5.2.5 [ Verify each charging pump develops a flow of 2 [36] gpm at a discharge pressure of r [2200] psig. CEOG STS FREQUENCY
$7. hours] 4 El days +--, In accordance with the lnservice Testing Program In accordance with the lnservice Testing Program
] Rev. 3.0, 03/31/04 ACTIONS (continued}
CONDITION D.Less than 100%of the D.1 EGGS flow equivalent to a single OPERABLE train available.
SURVEILLANCE REQUIREMENTS REQUIRED ACTION Enter LeO 3.0.3.ECCS-Operating 3.5.2 COMPLETION TIME Immediately SR 3.5.2.1 SURVEILLANCE
[Verify the following valves are in the listed position with power to the valve operator removed[and key locked in position].
FREQUENCY Valve Number[][][]Position[][][]Function[][][]SR 3.5.2.2 SR 3.5.2.3 SR 3.5.2.4 SR 3.5.2.5 GEOG STS Verify each EGGS 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.[Verify EGGS piping is full of water.Verify each ECCS pump's developed head at the test flow point is greater than or equal to the required developed head.[Verify each charging pump develops a flow of 2':[36]gpm at a discharge pressure of 2':[2200]psig.3.5.2-2 In accordance with the Inservice Testing Program In accordance with the Inservice Testing Program]Rev.3.0, 03/31/04 ECCS , Operating
 
====3.5.2 SURVEILLANCE====
REQUIREMENTS (continued)
SURVEILLANCE SR 3.5.2.6 Verify each ECCS automatic valve that is not locked, sealed, or otherwise secured in position, in the flow path actuates to the correct position on an actual or simulated actuation signal. Verify each ECCS pump starts automatically on an actual or simulated actuation signal. Verify each LPSl pump stops on an actual or simulated actuation signal. [ Verify, for each ECCS throttle valve listed below, each position stop is in the correct position. Valve Number
[ 1 [ I SR 3.5.2.10 Verify, by visual inspection, each ECCS train containment sump suction inlet is not restricted by debris and the suction inlet trash racks and screens show no evidence of structural distress or abnormal corrosion.
FREQUENCY 4 [I 81 months - '7 [I81 months - --" I181 months - CEOG STS Rev. 3.0, 03/31/04 ECCS-Operating 3.5.2 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.5.2.6 Verify each ECCS automatic valve that is not locked, sealed, or otherwise secured in position, in the flow path actuates to the correct position on an eInscrf1 actual or simulated actuation signal.SR 3.5.2.7 Verify each ECCS pump starts automatically on an W8J months actual or simulated actuation signal.(j:"'\Ser--:
SR 3.5.2.8 Verify each LPSI pump stops on an actual or W 8]months-1;..,--.., simulated actuation signal.
Irl..3t3r'
..
..........-,"..,-_...,SR 3.5.2.9[Verify, for each EGGS throttle valve listed below, m 8]months]each position stop is in the correct position.J Valve Number (.Inse r-t[][]SR 3.5.2.10 Verify, by visual inspection, each ECCS train[18J months containment sump suction inlet is not restricted by debris and the suction inlet trash racks and screens
.&#xa3;show no evidence of structural distress or abnormal corrosion.
1 GEOG STS Rev.3.0, 03/31/04 RWT 3.5.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.5.4.1 ----------------------*--------
NOTE .............................
[ Only required to be performed when ambient air temperature is c [40I0F or > [100]"F. ] -****----------------------------------------------*-----------------
Verify RWT borated water temperature is 2 [40I0F and 5 [I 00]"F. Verify RWT borated water volume is 2 [362,800 gallons, (88)%] [above the ECCS suction connection].
SR 3.5.4.3 Verify RWT boron concentration is 2 [I 7201 ppm and i [2500] ppm. CEOG STS FREQUENCY Rev. 3.0, 03/31/04 SURVEILLANCE REQUIREMENTS SURVEILLANCE RWT 3.5.4 FREQUENCY SR 3.5.4.1 SR 3.5.4.2 SR 3.5.4.3 CEOG STS-------------------------------NOTE-----------------------------
[Only required to be performed when ambient air temperature is<[40]OF or>[1 OO]OF.]Verify RWT borated water temperature is 2':[40]OF and:s[1 OO]OF.Verify RWT borated water volume is 2':[362,800 gallons, (88)%][above the ECCS suction connection].
Verify RWT boron concentration is 2::[1720]ppm and::;[2500]ppm.3.5.4-2 Rev.3.0, 03/31/04 TSP 3.5.5 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS)
 
====3.5.5 Trisodium====
Phosphate (TSP)
LC0 3.5.5 The TSP baskets shall contain 2 [291] ft3 of active TSP. APPLICABILITY: MODES 1,2, and 3. ACTIONS A. TSP not within limits. A.1 Restore TSP to within limits. 72 hours 6. Required Action and B.l Be in MODE 3. associated Completion Time not met. AND 8.2 Be in MODE 4. 6 hours [I 21 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.5.1 Verify the TSP baskets contain 2 [291] ft3 of 6 8] months 4 * . , trisodium phosphate.
SR 3.5.5.2 adequate pH adjustment of RWT water. CEOG STS Rev. 3.0. 03/31/04 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS)3.5.5 Trisodium Phosphate (TSP)LCO 3.5.5 The TSP baskets shall contain 2':[291]fe of active TSP.TSP 3.5.5 APPLICABILITY:
ACTIONS MODES 1, 2, and 3.CONDITION REQUIRED ACTION COMPLETION TIME A.TSP not within limits.A.1 Restore TSP to within 72 hours limits.B.Required Action and B.1 Be in MODE 3.6 hours associated Completion Time not met.AND B.2 Be in MODE 4.[12]hours SURVEILLANCE REQUIREMENTS SR 3.5.5.1 SR 3.5.5.2 CEOG STS SURVEILLANCE Verify the TSP baskets contain 2':[291]ft3 of trisodium phosphate.
Verify that a sample from the TSP baskets provides adequate pH adjustment of RWT water.3.5.5-1 FREQUENCY Rev.3.0, 03/31/04 Containment Air Locks (Atmospheric and Dual) 3.6.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.6.2.1 ------------------------------NOTES
.............................
I. An inoperable air lock door does not invalidate the previous successful performance of the overall air lock leakage test.
: 2. Results shall be evaluated against acceptance criteria applicable to SR 3.6.1 .I. Perform required air lock leakage rate testing in accordance with the Containment Leakage Rate Testing Program.
SR 3.6.2.2 Verify only one door in the air lock can be opened at a time. CEOG STS FREQUENCY In accordance with the Containment Leakage Rate Testing Program Rev. 3.0, 03/31/04 Containment Air Locks (Atmospheric and Dual)3.6.2 SURVEILLANCE REQUIREMENTS SR 3.6.2.1 SR 3.6.2.2 CEOG STS SURVEILLANCE
------------------------------
NOT E S-----------------------------
1.An inoperable air lock door does not invalidate the previous successful performance of the overall air lock leakage test.2.Results shall be evaluated against acceptance criteria applicable to SR 3.6.1.1.Perform required air lock leakage rate testing in accordance with the Containment Leakage Rate Testing Program.Verify only one door in the air lock can be opened at a time.3.6.2-4 FREQUENCY In accordance with the Containment Leakage Rate Testing Program Rev.3.0, 03/31/04 Containment Isolation Valves (Atmospheric and Dual)
 
====3.6.3 ACTIONS====
(continued)
CONDITION G. Required Action and associated Completion Time not met. REQUIRED ACTION F.3 Perform SR 3.6.3.6 for the resilient seal purge valves closed to comply with Required Action F.1. COMPLETION TIME Once per [ ] days ] G.l Be in MODE 3. G.2 Be in MODE 5. 6 hours 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.6.3.1 [ Verify each
[42] inch purge valve is sealed closed except for one purge valve in a penetration flow path while in Condition E of this LCO.
SR 3.6.3.2 Verify each
[8] inch purge valve is closed except when the [8] inch purge valves are open for pressure control, ALARA or air quality considerations for personnel entry, or for Surveillances that require the valves to be open. SR 3.6.3.3 -------------------------------NOTE
.............................. Valves and blind flanges in high radiation areas may be verified by use of administrative means. Verify each containment isolation manual valve and blind flange that is located outside containment and not locked, sealed, or otherwise secured and is required to be closed during accident conditions is closed, except for containment isolation valves that are open under administrative controls.
-. A "*- ., , . -. . - CEOG STS 3.6.3-6 FREQUENCY
+- 31 day$ ''I - - - 31 days +, C. \ Rev. 3.1, 12/01/05 Containment Isolation Valves (Atmospheric and Dual)3.6.3 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME F.3 Perform SR 3.6.3.6 for the Once per[]days]resilient seal purge valves closed to comply with Required Action F.1.G.Required Action and G.1 Be in MODE 3.6 hours associated Completion Time not met.AND G.2 Be in MODE 5.36 hours SURVEILLANCE REQUIREMENTS SR 3.6.3.1 SURVEILLANCE
[Verify each[42]inch purge valve is sealed closed except for one purge valve in a penetration flow path while in Condition E of this LCO.FREQUENCY SR 3.6.3.2 SR 3.6.3.3 Verify each[8]inch purge valve is closed except when the[8]inch purge valves are open for pressure control, ALARA or air quality considerations for personnel entry, or for Surveillances that require the valves to be open.-------------------------------NOTE
------------------------------
Valves and blind flanges in high radiation areas may be verified by use of administrative means.days CEOG STS Verify each containment isolation manual valve and blind flange that is located outside containment and not locked, sealed, or otherwise secured and is required to be closed during accident conditions is closed, except for containment isolation valves that are open under administrative controls.3.6.3-6 Rev.3.1,12/01/05 Containment Isolation Valves (Atmospheric and Dual) SURVEILLANCE REQUl REMENTS (continued)
SURVEILLANCE SR 3.6.3.4 ------*------------------------
NOTE ..............................
Valves and blind flanges in high radiation areas may be verified by use of administrative means.
--*-----------------------**-------------------------**-------------- Verify each containment isolation manual valve and blind flange that is located inside containment and not locked, sealed, or otherwise secured and required to be closed during accident conditions is closed, except for containment isolation valves that are open under administrative controls.
SR 3.6.3.5 Verify the isolation time of each automatic power operated containment isolation valve is within limits.
SR 3.6.3.6 Perform leakage rate testing for containment purge valves with resilient seals.
SR 3.6.3.7 Verify each automatic containment isolation valve that is not locked, sealed, or otherwise secured in position, actuates to the isolation position on an actual or simulated actuation signal. SR 3.6.3.8
[ Verify each [ ] inch containment purge valve is blocked to restrict the valve from opening
> [50]%. - SR 3.6.3.9 [ Verify the combined leakage rate for all secondary containment bypass leakage paths is 5 [ La] when pressurized to r [ psig]. CEOG STS 3.6.3-7 FREQUENCY Prior to entering MODE 4 from MODE 5 if not performed within the previous 92 days [ In accordance with the Inservice Testing Pro ram or 92 days- Within 92 days I after opening the valve In accordance with the Containment Leakage Rate Testing Program
] Rev. 3.1, l2/Ol!O5 Containment Isolation Valves (Atmospheric and Dual)3.6.3 SURVEILLANCE REQUIREMENTS (continued)
SR 3.6.3.4 SR 3.6.3.5 SR 3.6.3.6 SR 3.6.3.7 SR 3.6.3.8 SR 3.6.3.9 CEOG STS SURVEILLANCE
-------------------------------
NOT E------------------------------
Valves and blind flanges in high radiation areas may be verified by use of administrative means.Verify each containment isolation manual valve and blind flange that is located inside containment and not locked, sealed, or otherwise secured and required to be closed during accident conditions is closed, except for containment isolation valves that are open under administrative controls.Verify the isolation time of each automatic poweroperatedcontainment isolation valve is within limits.Perform leakage rate testing for containment purge valves with resilient seals.Verify each automatic containment isolation valve that is not locked, sealed, or otherwise secured in position, actuates to the isolation position on an actual or simulated actuation signal.[Verify each[J inch containment purge valve is blocked to restrict the valve from opening>[50J%.[Verify the combined leakage rate for all secondary containment bypass leakage paths is s:[La]when pressurized to 2':[psig}.3.6.3-7 FREQUENCY Prior to entering MODE 4 from MODE 5 if not performed within the previous 92 days[In accordance with the Inservice
'IT)or 92 daysA';r;eAi[[84 daysAND Within 92 days after opening the (--t valve.lreei 1-f[18}months f-."" l!.,''.........In accordance with the Containment Leakage Rate Testing Program]Rev.3.1, 12/01/05 Containment Pressure (Atmospheric and Dual)
 
===3.6 CONTAINMENT===
SYSTEMS
 
====3.6.4 Containment====
Pressure (Atmospheric and Dual) LC0 3.6.4 Containment pressure shall be [Dual: > 14.375 psia and < 27 inches water gauge] [or] [Atmospheric:
2 -0.3 psig and 5 +I .5 psig]. APPLICABILITY: MODES 1, 2, 3, and 4. ACTIONS CONDITION A. Containment pressure not within limits.
B. Required Action and associated Completion Time not met. REQUIRED ACTION A.l Restore containment pressure to within limits.
B.l Be in MODE 3. AND 6.2 Be in MODE 5. COMPLETION TIME 1 hour 6 hours 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.1 Verify containment pressure is within limits. CEOG STS Rev. 3.0, 03/31/04 Containment Pressure (Atmospheric and Dual)3.6.4 3.6 CONTAINMENT SYSTEMS 3.6.4 Containment Pressure (Atmospheric and Dual)LCO 3.6.4 Containment pressure shall be[Dual:>14.375 psia and<27 inches water gauge][or][Atmospheric:-0.3 psig and:;+1.5 psig].APPLICABILITY:
ACTIONS MODES 1, 2, 3, and 4.CONDITION REQUIRED ACTION COMPLETION TIME A.Containment pressure A.1 Restore containment 1 hour not within limits.pressure to within limits.B.Required Action and B.1 Be in MODE 3.6 hours associated Completion Time not met.AND B.2 Be in MODE 5.36 hours SURVEILLANCE REQUIREMENTS SR 3.6.4.1 CEOG STS SURVEILLANCE Verify containment pressure is within limits.3.6.4-1 FREQUENCY Rev.3.0.03/31/04 Containment Air Temperature (Atmospheric and Dual) 3.6.5 3.6 CONTAINMENT SYSTEMS
 
====3.6.5 Containment====
Air Temperature (Atmospheric and Dual) LC0 3.6.5 Containment average air temperature shall be 5 [120IoF. APPLICABILITY: MODES 1, 2, 3, and 4. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Containment average air temperature not within limit. 1 8.2 Be in MODE 5. 1 36 hours B. Required Action and associated Completion Time not met. SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY A.l Restore containment average air temperature to within limit. SR 3.6.5.1 Verify containment average air temperature is within 1 @ hours &--h 8 hours B.l Be in MODE 3. - AND limit. 6 hours CEOG STS Rev. 3.0, 03/31/04 Containment Air Temperature (Atmospheric and Dual)3.6.5 3.6 CONTAINMENT SYSTEMS 3.6.5 Containment Air Temperature (Atmospheric and Dual)LCO 3.6.5 Containment average air temperature shall be[120JoF.APPLICABILITY:
ACTIONS MODES 1, 2, 3, and 4.CONDITION REQUIRED ACTION COMPLETION TIME A.Containment average air A.1 Restore containment 8 hourstemperaturenot within average air temperature to limit.within limit.B.Required Action and B.1 Be in MODE 3.6 hours associated Completion Time not met.AND B.2 Be in MODE 5.36 hours SURVEILLANCE REQUIREMENTS SR 3.6.5.1 CEOG STS SURVEILLANCE Verify containment average air temperature is within limit.3.6.5-1 FREQUENCY Rev.3.0, 03/31104 ACTIONS (continued)
CONDITION Containment Spray and Cooling Systems (Atmospheric and Dual) 3.6.6A E. Two containment cooling trains inoperable.
F. Required Action and associated Completion Time of Condition C, D, or E not met. G. Two containment spray trains inoperable.
Any combination of three or more trains inoperable. REQUIRED ACTION
*.I Restore one containment cooling train to OPERABLE status. F.l Be in MODE 3. F.2 Be in MODE 5. G.1 Enter LC0 3.0.3. COMPLETION TIME 72 hours 6 hours 36 hours -- - Immediately SURVEILLANCE REQUIREMENTS - SURVEILLANCE SR 3.6.6A.1 Verify each containment spray 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.
SR 3.6.6A.2 Operate each containment cooling train fan unit for 2 15 minutes. SR 3.6.6A.3 Verify each containment cooling train cooling water flow rate is 2 [2000] gpm to each fan cooler.
FREQUENCY El days 4- Z days CEOG STS Rev. 3.1, 12/01/05 Containment Spray and Cooling Systems (Atmospheric and Dual)3.6.6A ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME E.Two containment cooling E.1 Restore one containment 72 hours trains inoperable.
cooling train to OPERABLE status.F.Required Action and F.1 Be in MODE 3.6 hours associated Completion Time of Condition C, D, AND or E not met.F.2 Be in MODE 5.36 hours G.Two containment spray G.1 Enter LCO 3.0.3.Immediately trains inoperable.
OR Any combination of three or more trains inoperable.
SURVEILLANCE REQUIREMENTS SR 3.6.6A.1 SR 3.6.6A.2 SR 3.6.6A.3 CEOG STS SURVEILLANCE Verify each containment spray 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.Operate each containment cooling train fan unit for 2:: 15 minutes.Verify each containment cooling train cooling water flow rate is 2::[2000J gpm to each fan cooler.3.6.6A-2 FREQUENCY Rev.3.1,12/01/05 Containment Spray and Cooling Systems (Atmospheric and Dual) 3.6.6A SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE SR 3.6.6A.4 [ Verify the containment spray piping is full of water to the [7 001 ft level in the containment,spray header. SR 3.6.6A.5 Verify each containment spray pump's developed head at the flow test point is greater than or equal to the required developed head.
SR 3.6.6A.6 Verify each automatic containment spray valve in the flow path that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.
SR 3.6.6A.7 Verify each containment spray pump starts automatically on an actual or simulated actuation signal. SR 3.6.6A.8 Verify each containment cooling train starts automatically on an actual or simulated actuation signal. SR 3.6.6A.9 Verify each spray nozzle is unobstructed. CEOG STS FREQUENCY In accordance with the Inservice Testing Program
+ 1181 months e> - [I 81 months f ---, [At first refueling
] Rev. 3.1, 12/01/05 Containment Spray and Cooling Systems (Atmospheric and Dual)3.6.6A SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.6.6AA[Verify the containment spray piping is full of water[I1to the[1DDJ ft level in the containmentspray header.(Inse.rtl)
SR 3.6.6A.5 Verify each containment spray pump's developed In accordance headatthe flow test point is greater than or equal to with the Inservice the required developed head.Testing Program SR 3.6.6A6 Verify each automatic containment spray valve in iliB]
the flow path that is not locked, sealed, or otherwise (;c-;,serTj) secured in position, actuates to the correct position on an actual or simulated actuation signal...SR 3.6.6A?Verify each containment spray pump starts n!.8]monthsautomatically on an actual or simulated actuation (I;:e.-1-signal.SR 3.6.6A.B Verify each containment cooling train starts lE81 months.automatically on an actual or simulated actuation signal.
SR 3.6.6A9 Verify each spray nozzle is unobstructed.
[At first refueling]
AND[0 years C T 1)CEOG STS 3.6.6A-3 Rev.3.1, 12/01/05 ACTIONS (continued)
CONDITION Containment Spray and Cooling Systems (Atmospheric and Dual) 3.6.66 E. Two containment cooling trains inoperable.
F. Required Action and associated Completion Time of Condition A, 6, C, D, or E not met. G. Any combination of three or more trains inoperable. REQUIRED ACTION E.l Restore one containment cooling train to OPERABLE status. F.l Be in MODE 3. AND F.2 Be in MODE 5. G.l Enter LC0 3.0.3. SURVEILLANCE REQUIREMENTS COMPLETION TIME 72 hours 6 hours 36 hours Immediately SURVEILLANCE SR 3.6.6B.1 Verify each containment spray 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.
SR 3.6.6B.2 Operate each containment cooling train fan unit for 2 15 minutes. SR 3.6.6B.3 Verify each containment cooling train cooling water flow rate is 2 [2000] gpm to each fan cooler.
FREQUENCY CEOG STS Rev. 3.1, 12/01/05 Containment Spray and Cooling Systems (Atmospheric and Dual)3.6.66 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME E.Two containment cooling E.1 Restore one containment 72 hours trains inoperable.
cooling train to OPERABLE status.F.Required Action and F.1 Be in MODE 3.6 hours associated Completion Time of Condition A, B, AND C, D, or E not met.F.2 Be in MODE 5.36 hours G.Any combination of three G.1 Enter LCO 3.0.3.Immediately or more trains inoperable.
SURVEILLANCE REQUIREMENTS SR 3.6.6B.1 SR 3.6.6B.2 SR 3.6.6B.3 CEOG STS SURVEILLANCE Verify each containment spray 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.Operate each containment cooling train fan unit for;:::: 15 minutes.Verify each containment cooling train cooting water flow rate is;::::[2000]gpm to each fan cooler.3.6.68-2 FREQUENCY1 days t(-:-,.,-"
[j 1 days Rev.3.1,12/01/05 Containment Spray and Cooling Systems (Atmospheric and Dual) SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE SR 3.6.68.4 [ Verify the containment spray piping is full of water to the [I001 ft level in the containment spray header. SR 3.6.6B.5 Verify each containment spray pump's developed head at the flow test point is greater than or equal to the required developed head.
SR 3.6.68.6 Verify each automatic containment spray valve in the flow path that is not locked, sealed, or otherwise secured in position, actuates to its correct position on an actual or simulated actuation signal.
SR 3.6.6B.7 Verify each containment spray pump starts automatically on an actual or simulated actuation signal. SR 3.6.6B.8 Verify each containment cooling train starts automatically on an actual or simulated actuation signal. SR 3.6.6B.9 Verify each spray nozzle is unobstructed. CEOG STS FREQUENCY In accordance with the Inservice Testing Program - [I81 months* - :18] months &'-, [ At first refueling
] Rev. 3.1, 12/01/05 Containment Spray and Cooling Systems (Atmospheric and Dual)3.6.68 SURVEILLANCE REQUIREMENTS (continued)
SU RVEI LLANCE FREQUENCY SR 3.6.68.4[Verify the containment spray piping is full of water to the[100J ft level in the containment spray header.Ihser.SR 3.6.68.5 Verify each containment spray pump's developed In accordance head at the flow test point is greater than or equal to with the Inservice the required developed head.Testing Program SR 3.6.68.6 Verify each automatic containment spray valve in[118) the flow path that is not locked, sealed, or otherwise secured in position, actuates to its correct position CIr15ert on an actual or simulated actuation signal.
........SR 3.6.68.7 Verify each containment spray pump starts (18)months t:::--." automatically on an actual or simulated actuation f".:.-,-_._-_.':t"--
signal.
SR 3.6.68.8 Verify each containment cooling train starts ffi 8]months J:::'-"'''''-..
automatically on an actual or simulated actuation---"A'-signal.(I:r6 cr::,'.',,"':
....." SR 3.6.68.9 Verify each spray nozzle is unobstructed.
[At first refueling]
AND (IO years 0:;e.t CEOG STS 3.6.68-3 Rev.3.1,12/01/05 Spray Additive System (Atmospheric and Dual) 3.6.7 3.6 CONTAINMENT SYSTEMS
 
====3.6.7 Spray====
Additive System (Atmospheric and Dual)
LC0 3.6.7 The Spray Additive System shall be OPERABLE.
APPLICABILITY:
MODES I, 2, 3, and [4]. ACTIONS CONDITION A. Spray Additive System inoperable.
B. Required Action and associated Completion Time not met. REQUIRED ACTION A.l Restore Spray Additive System to OPERABLE status. B.l Be in MODE 3. B.2 Be in MODE 5. - COMPLETION TIME - 72 hours 6 hours 84 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.6.7.1 Verify each spray additive 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.
SR 3.6.7.2 Verify spray additive tank solution volume is 2 [816] gal [go%] and 5 [896] gal [loo%]. SR 3.6.7.3 Verify spray additive tank
[N2H4] solution concentration is 2 [33]% and i [35]% by weight. CEOG STS 3.6.7-1 FREQUENCY days *. <h Rev. 3.0, 03/31/04 Spray Additive System (Atmospheric and Dual)3.6.7 3.6CONTAINMENTSYSTEMS
 
====3.6.7 Spray====
Additive System (Atmospheric and Dual)LCO 3.6.7 The Spray Additive System shall be OPERABLE.APPLICABILITY:
ACTIONS MODES 1, 2, 3, and[4].CONDITION REQUIRED ACTION COMPLETION TIME A.Spray Additive System A.1 Restore Spray Additive 72 hours inoperable.
System to OPERABLE status.--_...._, B.Required Action and B.1 Be in MODE 3.6 hours associated Completion Time not met.AND B.2 Be in MODE 5.84 hours SURVEILLANCE REQUIREMENTS SR 3.6.7.1 SR 3.6.7.2 SR 3.6.7.3 CEOG STS SURVEILLANCE Verify each spray additive 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.Verify spray additive tank solution volume is 2':[816]gal[90%]and:-::;[896]gal[100%].Verify spray additive tank[N 2 H 4 J solution concentration is 2':[33]%and:-::;[35]%by weight.3.6.7-1 FREQUENCY Rev.3.0, 03/31/04 Spray Additive System (Atmospheric and Dual) 3.6.7 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE SR 3.6.7.4 [ Verify each spray additive pump develops a differential pressure of
[I 001 psid on recirculation flow. SR 3.6.7.5 Verify each spray additive automatic valve in the flow path that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.
SR 3.6.7.6 [ Verify spray additive flow [rate] from each solution's flow path. FREQUENCY In accordance with the Inservice Testing Program
] CEOG STS Rev. 3.0, 03/31/04 Spray Additive System (Atmospheric and Dual)3.6.7 SURVEILLANCE REQUIREMENTS (continued)
SR 3.6.7.4 SR 3.6.7.5 SR 3.6.7.6 CEOG STS SURVEILLANCE
[Verify each spray additive pump develops a differential pressure of[100]psid on recirculation flow.Verify each spray additive automatic valve in the flow path that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.[Verify spray additive flow[rate]from each solution's flow path.3.6.7-2 FREQUENCY In accordance with the Inservice Testing Program]Rev.3.0, 03/31/04 SBEACS (Dual) 3.6.8 3.6 CONTAINMENT SYSTEMS
 
====3.6.8 Shield====
Building Exhaust Air Cleanup System (SBEACS) (Dual)
LC0 3.6.8 Two SBEACS trains shall be OPERABLE.
APPLICABILITY:
MODES 1, 2, 3, and 4. ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One SBEACS train A.1 Restore train to inoperable. OPERABLE status.
7 days *3. Required Action and B.l Be in MODE 3. Associated Completion Time not met.
AND 1 B-2 Be in MODE 5. 6 hours 36 hours SURVEILLANCE REQUIREMENTS - SURVEILLANCE SR 3.6.8.1 Operate each SBEACS train for [2 10 continuous hours with the heaters operating or (for systems without heaters) 2 15 minutes].
SR 3.6.8.2 Perform required SBEACS filter testing in accordance with the Ventilation Filter Testing Program (VFTP).
SR 3.6.8.3 Verify each SBEACS train actuates on an actual or simulated actuation signal. CEOG STS FREQUENCY In accordance with the VFTP Rev. 3.0, 03/31/04 3.6 CONTAINMENT SYSTEMS 3.6.8 Shield Building Exhaust Air Cleanup System (SBEACS)(Dual)LCO 3.6.8 Two SBEACS trains shall be OPERABLE.SBEACS (Dual)3.6.8 APPLICABILITY:
ACTIONS MODES 1, 2, 3, and 4.CONDITION REQUIRED ACTION COMPLETION TIME A.One SBEACS train A.1 Restore train to 7 days inoperable.
OPERABLE status.B.Required Action and B.1 Be in MODE 3.6 hours Associated Completion Time not met.AND B.2 Be in MODE 5.36 hours SURVEILLANCE REQUIREMENTS SR 3.6.8.1 SR 3.6.8.2 SR 3.6.8.3 CEOG STS SURVEILLANCE Operate each SBEACS train for[2: 10 continuous hours with the heaters operating or (for systems without heaters)2: 15 minutes].Perform required SBEACS filter testing in accordance with the Ventilation Filter Testing Program (VFTP).Verify each SBEACS train actuates on an actual or simulated actuation signal.3.6.8-1 FREQUENCY In accordance with the VFTP IT!8]monthsCrr, set:Ij)Rev.3.0, 03/31/04 SBEACS (Dual)
 
====3.6.8 SURVEILLANCE====
REQUIREMENTS (continued)
SURVEILLANCE SR 3.6.8.4 [ Verify each SBEACS filter bypass damper can be opened. SR 3.6.8.5 Verify each SBEACS train flow rate is 2 [ ] cfm. CEOG STS FREQUENCY
[I 81 months ] TAGGERED +, Rev. 3.0, 03/31/04 SURVEILLANCE SBEACS (Dual)3.6.8 FREQUENCY SR 3.6.8.4 SR 3.6.8.5 CEOG STS[Verify each SBEACS filter bypass damper can be opened.Verify each SBEACS train flow rate is 2:[]cfm.3.6.8-2'C." lJ}8J months J 1[18J months on a t-)TEST BASIS (..'TI\.-".:I:r6erL'-!J Rev.3.0, 03/31/04 HMS (Atmospheric and Dual) 3.6.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.6.9.1 Operate each HMS train for 2 15 minutes. Verify each HMS train flow rate on slow speed is 2 [37,000] cfm. Verify each HMS train starts on an actual or simulated actuation signal.
CEOG STS -- FREQUENCY b8] months (cl (;L b - : ..- *:i~s - h8l months Rev. 3.0, 03131104 HMS (Atmospheric and Dual)3.6.9 SURVEILLANCE REQUIREMENTS SR 3.6.9.1 SR 3.6.9.2 SR 3.6.9.3 CEOG STS SURVEILLANCE Operate each HMS train for15 minutes.Verify each HMS train flow rate on slow speed is;;:::[37,000]cfm.Verify each HMS train starts on an actual or simulated actuation signal.FREQUENCY Rev.3.0, 03/31/04 ICS (Atmospheric and Dual) 3.6.10 3.6 CONTAINMENT SYSTEMS 3.6.10 Iodine Cleanup System (ICS) (Atmospheric and Dual)
LC0 3.6.10 [Two] ICS trains shall be OPERABLE.
APPLICABILITY:
MODES 1, 2, 3, and 4. ACTIONS CONDITION A. One ICS train inoperable.
: 6. Required Action and associated Completion Time not met. REQUIRED ACTION A.1 Restore ICS train to OPERABLE status.
B.l Be in MODE 3. AND - B.2 Be in MODE 5. COMPLETION TIME 7 days 6 hours 36 hours SURVEILLANCE REQUIREMENTS - - SURVEILLANCE SR 3.6.10.1 Operate each ICS train for [2 10 continuous hours with heaters operating or (for systems without heaters) 2 15 minutes].
SR 3.6.10.2 Perform required ICS filter testing in accordance with the Ventilation Filter Testing Program (VFTP). SR 3.6.10.3 Verify each ICS train actuates on an actual or simulated actuation signal. CEOG STS FREQUENCY In accordance with the VFTP @8] months 4. .,\ Rev. 3.0, 03/31/04 ICS (Atmospheric and Dual)3.6.10 3.6 CONTAINMENT SYSTEMS 3.6.10 Iodine Cleanup System (ICS)(Atmospheric and Dual)LCO 3.6.10 APPLICABILITY:
ACTIONS[Two]ICS trains shall be OPERABLE.MODES 1, 2, 3, and 4.CONDITION REQUIRED ACTION COMPLETION TIME A.One ICS train A.1 Restore ICS train to 7 days inoperable.
OPERABLE status._.
B.Required Action and B.1 Be in MODE 3.6 hours associated Completion Time not met.AND B.2 Be in MODE 5.36 hours SURVEILLANCE REQUIREMENTS SR 3.6.10.1 SR 3.6.10.2 SURVEILLANCE Operate each ICS train for[';::>: 10 continuous hours with heaters operating or (for systems without heaters)2:: 15 minutes].Perform required ICS filter testing in accordance with the Ventilation FilterTestingProgram (VFTP).FREQUENCY In accordance with the VFTP SR 3.6.10.3 CEOG STS Verify each ICS train actuates on an actual or simulated actuation signal.3.6.10-1 Rev.3.0, 03/31/04 ICS (Atmospheric and Dual) 3.6.10 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE SR 3.6.10.4 [ Verify each ICS filter bypass damper can be opened. CEOG STS FREQUENCY Rev. 3.0, 03/31/04 SURVEILLANCE ICS (Atmospheric and Dual)3.6.10 FREQUENCY SR 3.6.10.4 CEOG STS[Verify each ICS filter bypass damper can be opened.3.6.10-2 Rev.3.0.03/31/04 Shield Building (Dual) 3.6.1 1 3.6 CONTAINMENT SYSTEMS 3.6.1 1 Shield Building (Dual)
LC0 3.6.1 1 Shield building shall be OPERABLE.
APPLICABILITY:
MODES 1, 2, 3, and 4. ACTIONS 1- - CONDITION I REQUIRED ACTION I COMPLETION TIME A. Shield building inoperable.
A.l Restore shield building to OPERABLE status. 13.2 Be in MODE 5. 24 hours B. Required Action and associated Completion Time not met. 6 hours 36 hours B.l Be in MODE 3. AND SURVEILLANCE REQUIREMENTS - - SURVEILLANCE SR 3.6.11.1 Verify annulus negative pressure is > [5] inches water gauge. SR 3.6.11.2 Verify one shield building access door in each access opening is closed. SR 3.6.11.3 Verify shield building structural integrity by performing a visual inspection of the exposed interior and exterior surfaces of the shield building.
FREQUENCY During shutdown for SR 3.6.1 .I Type A tests CEOG STS Rev. 3.0, 03/31/04 3.6 CONTAINMENT SYSTEMS Shield Building (Dual)3.6.11 3.6.11 Shield Building (Dual)LCO 3.6.11 APPLICABILITY:
ACTIONS Shield building shall be OPERABLE.MODES 1, 2, 3, and 4.CONDITION REQUIRED ACTION COMPLETION TIME A.Shield building A.1 Restore shield building to 24 hours inoperable.
OPERABLE status.._.B.Required Action and B.1 Be in MODE 3.6 hours associated Completion Time not met.AND B.2 Be in MODE 5.36 hours SURVEILLANCE REQUIREMENTS SR 3.6.11.1 SR 3.6.11.2 SR 3.6.11.3 CEOG STS SURVEILLANCE Verify annulus negative pressure is>[5]inches water gauge.Verify one shield building access door in each access opening is closed.Verifyshieldbuilding structural integrity by performing a visual inspection of the exposed interior and exterior surfaces of the shield bUilding.3.6.11-1 FREQUENCY During shutdown for SR 3.6.1.1 Type A tests Rev.3.0, 03/31/04 Shield Building (Dual) SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE SR 3.6.1 1.4 Verify the shield building can be maintained at a pressure equal to or more negative than [-0.251 inch water gauge in the annulus by one Shield Building Exhaust Air Cleanup System train with a final flow rate I [ ] cfm within [I] minute after a start signal. CEOG STS FREQUENCY
[I81 months on a 'S TAGGERED TEST BASIS for each Shield Building Exhaust Air Cleanup System d379 Rev. 3.0, 03/31/04 SURVEILLANCE Shield Building (Dual)3.6.11 FREQUENCY SR 3.6.11.4 CEOG STS Verify the shield building can be maintained at a pressure equal to or more negative than[-0.25]inch water gauge in the annulus by one Shield Building Exhaust Air Cleanup System train with a final flow rate:s;[J cfm within[1 J minute after a start signal.3.6.11-2 1[18]months on a'-STAGGERED TEST BASIS for each Shield Building Exhaust Air
*System]JY2eYll Rev.3.0, 03/31/04 SURVEILLANCE REQUIREMENTS SURVEILLANCE Verify the isolation time of each MSlV is [4.6] seconds. In accordance with the Inservice Testing program CEOG STS Rev. 3.0, 03/31/04 SURVEILLANCE REQUIREMENTS SURVEILLANCE MSIVs 3.7.2 FREQUENCY SR 3.7.2.1 SR 3.7.2.2 CEOG STS Only required to be performed in MODES 1 and 2.Verify the isolation time of each MSIV is:5[4.6]seconds.-------------------------------NOTE---*--------------------------
Only required to be performed in MODES 1 and 2.Verify each MSIV actuates to the isolation position on an actual or simulated actuation signal.3.7.2-2 In accordance with the I nservice Testing Program Rev.3.0, 03/31/04 MFlVs [and [MFIV] Bypass Valves]
 
====3.7.3 SURVEILLANCE====
REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.3.2 Verify each MFlV [and [MFIV] bypass valve] actuates to the isolation position on an actual or simulated actuation signal. SR 3.7.3.1 Verify the isolation time of each MFlV [and [MFIVJ bypass valve] is I [7] seconds. CEOG STS In accordance with the Inservice Testing Program Rev. 3.0, 03/31/04 MFIVs[and[MFIV]Bypass Valves]3.7.3 SURVEILLANCE REQUIREMENTS SR 3.7.3.1 SR 3.7.3.2 CEOG STS SURVEILLANCE Verify the isolation time of each MFIV[and[MFIV]bypass valve]is[7]seconds.Verify each MFIV[and[MFIV]bypass valve]actuates to the isolation position on an actual or simulated actuation signal.3.7.3-2 FREQUENCY In accordance with the Inservice Testing Program[i18J Rev.3.0, 03/31/04 ADVs 3.7.4 3.7 PLANT SYSTEMS
 
====3.7.4 Atmospheric====
 
Dump Valves (ADVs) LC0 3.7.4 [Two] ADV lines shall be OPERABLE.
APPLICABILITY:
MODES 1, 2, and 3, [MODE 4 when steam generator is being relied upon for heat removal].
ACTIONS CONDITION A. One required ADV line inoperable.
: 6. Two or more [required] ADV lines inoperable.
C. Required Action and associated Completion Time not met. REQUIRED ACTION A.l Restore ADV line to OPERABLE status.
B.l Restore all but one ADV line to OPERABLE status.
C.l Be in MODE 3. C.2 Be in MODE 4 without reliance upon steam generator for heat removal. COMPLETION TIME 7 days 24 hours 6 hours [24] hours ] SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.1 Verify one complete cycle of each ADV CEOG STS Rev. 3.0, 03/31/04 ADVs 3.7.4 3.7 PLANT SYSTEMS 3.7.4 Atmospheric Dump Valves (ADVs)LCO 3.7.4[Two]ADV lines shall be OPERABLE.APPLICABILITY:
ACTIONS MODES 1, 2, and 3,[MODE 4 when steam generator is being relied upon for heat removal].CONDITION REQUIRED ACTION COMPLETION TIME A.One required ADV line A.1 Restore ADV line to 7 days inoperable.
OPERABLE status..,_..._--B.Two or more[required]
B.1 Restore all but one ADV 24 hours ADV lines inoperable.
line to OPERABLE status.C.Required Action and C.1 Be in MODE 3.6 hours associated Completion Time not met.[AND C.2 Be in MODE 4 without[24]hours]reliance upon steam generator for heat removal.SURVEILLANCE REQUIREMENTS SR 3.7.4.1 CEOG STS SURVEILLANCE Verify one complete cycle of each ADV.3.7.4-1 FREQUENCY W8]months Rev.3.0, 03/31/04 ADVs 3.7.4 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.7.4.2 [ Verify one complete cycle of each ADV block valve. CEOG STS Rev. 3.0, 03/31/04 SURVEILLANCE ADVs 3.7.4 FREQUENCY SR 3.7.4.2 CEOGSTS[Verify one complete cycle of each ADV block valve.3.7.4-2 Rev.3.0, 03/31/04 AFW System
 
====3.7.5 ACTIONS====
(continued)
CONDITION E. Required AFW train inoperable in MODE 4. REQUIRED ACTION E.1 -..-------------
NOTE --------------
LC0 3.0.3 and all other LC0 Required Actions requiring MODE changes are suspended until one AFW train is restored to OPERABLE status.
..................................... Initiate action to restore one AFW train to OPERABLE status. COMPLETION TIME Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.7.5.1 Verify each AFW manual, power operated, and automatic valve in each water flow path and in both steam supply flow paths to the steam turbine driven pump, that is not locked, sealed, or otherwise secured in position, is in the correct position.
SR 3.7.5.2 -------------------------------NOTE
.............................
Not required to be performed for the turbine driven AFW pump until
[24] hours after reaching
[800] psig in the steam generators.
--------------------------------------------------------+------------ Verify the developed head of each AFW pump at the flow test point is greater than or equal to the required developed head.
FREQUENCY In accordance with the Inservice Testing Program CEOG STS Rev. 3.1, 12/01/05 AFW System 3.7.5 ACTIONS (continued)
CONDITION E.Required AFW train inoperable in MODE 4.E.1 REQUIRED ACTION h__NOTE--------------
LCO 3.0.3 and all other LCD Required Actions requiring MODE changes are suspended until one AFW train is restored to OPERABLE status.COMPLETION TIME SURVEILLANCE REQUIREMENTS Initiate action to restore one Immediately AFW train to OPERABLE status.SR 3.7.5.1 SR 3.7.5.2 CEOG STS SURVEILLANCE Verify each AFW manual, power operated, and automatic valve in each water flow path and in both steam supply flow paths to the steam turbine driven pump, that is not locked, sealed, or otherwise secured in position, is in the correct position.-------------------------------
NOT E-----------------------------
Not required to be performed for the turbine driven AFW pump until[24]hours after reaching[800]psig in the steam generators.
Verify the developed head of each AFW pumpatthe flow test point is greater than or equal to the required developed head.3.7.5-3 FREQUENCY errS e.l,t 1.In accordance with the Inservice Testing Program Rev.3.1,12/01/05 AFW System 3.7.5 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE SR 3.7.5.3 ..............................
NOTES .............................
: 1. Not required to be performed for the turbine driven AFW pump until
[24] hours after reaching
[800] psig in the steam generators.
: 2. Not required to be met in MODE 4 when steam generator is relied upon for heat removal. Verify each AFW automatic valve that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.
SR 3.7.5.4 ..............................
NOTES ----------------- - -----------
: 1. Not required to be performed for the turbine driven AFW pump until
[24] hours after reaching
[800] psig in the steam generators.
: 2. Not required to be met in MODE 4 when steam generator is relied upon for heat removal.
---+---------------------------*****--------------------------+-+---- Verify each AFW pump starts automatically on an actual or simulated actuation signal when in MODE 1, 2, or 3. SR 3.7.5.5 Verify the proper alignment of the required AFW flow paths by verifying flow from the condensate storage tank to each steam generator.
CEOG STS FREQUENCY b8] months C--\ Prior to entering MODE 2 whenever unit has been in MODE 5, MODE 6, or defueled for a cumulative period of > 30 days Rev. 3.1, 12/01/05 REQUIREMENTS (continued)
SURVEILLANCE AFW System 3.7.5 FREQUENCY SR 3.7.5.3 SR 3.7.5.4 SR 3.7.5.5 CEOG STS------------------------------NOTES-----------------------------
1.Not required to be performed for the turbine driven AFW pump until[24J hours after reaching[800J psig in the steam generators.
2.Not required to be met in MODE 4 when steam generator is relied upon for heat removal.Verify each AFW automatic valve that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.------------------------------NOTES-----------------------------
1.Not required to be performed for the turbine driven AFW pump until[24]hours after reaching[800]psig in the steam generators.
2.Not required to be met in MODE 4 when steam generator is relied upon for heat removal.Verify each AFW pump starts automatically on an actual or simulated actuation signal when in MODE 1,2, or 3.Verify the proper alignment of the required AFW flow paths by verifying flow from the condensate storage tank to each steam generator.
3.7.5-4 IT!8J monthsPrior to entering MODE 2 whenever unit has been in MODE 5, MODE 6, or defueled for a cumulative period of>30 days Rev.3.1,12/01/05 CST 3.7.6 3.7 PLANT SYSTEMS
 
====3.7.6 Condensate====
Storage Tank (CST)
LC0 3.7.6 The CST shall be OPERABLE.
APPLICABILITY:
MODES 1, 2, and 3, [MODE 4 when steam generator is relied upon for heat removal].
ACTIONS CONDITION A. CST inoperable.
B. Required Action and associated Completion Time not met. REQUIRED ACTION A.l Verify OPERABILITY of backup water supply. A.2 Restore CST to OPERABLE status.
B.l Be in MODE 3. B.2 Be in MODE 4 without reliance on steam generator for heat removal.
COMPLETION TIME 4 hours Once per 12 hours thereafter 7 days 6 hours [24] hours SURVEILLANCE REQUIREMENTS SURVEILLANCE I FREQUENCY SR 3.7.6.1 Verify CST level is 2 [350,000]
gal. 1 hours a$, CEOG STS 3.7.6-1 Rev. 3.0, 03/31/04 CST 3.7.6 3.7 PLANTSYSTEMS
 
====3.7.6 Condensate====
Storage Tank (CST)LCO 3.7.6 The CST shall be OPERABLE.APPLICABILITY:
ACTIONS MODES 1, 2, and 3,[MODE 4 when steam generator is relied upon for heat removal].CONDITION REQUIRED ACTION COMPLETION TIME A.CST inoperable.
A.1 Verify OPERABILITY of 4 hours backup water supply.AND Once per 12 hours thereafter AND A.2 Restore CST to 7 days OPERABLE status.B.Required Action and B.1 Be in MODE 3.6 hours associated Completion Time not met.AND B.2 Be in MODE 4 without[24]hours reliance on steam generator for heat removal.SURVEILLANCE REQUIREMENTS SR 3.7.6.1 CEOG STS SURVEILLANCE Verify CST level is 2[350,000]gal.3.7.6-1 FREQUENCY@hours Rev.3.0, 03/31/04 CCW System 3.7.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.7.7.1 ------------------------------*
NOTE ..............................
Isolation of CCW flow to individual components does not render the CCW System inoperable. Verify each CCW manual, power operated, and automatic valve in the flow path servicing safety related equipment, that is not locked, sealed, or otherwise secured in position, is in the correct position.
SR 3.7.7.2 Verify each CCW automatic valve in the flow path that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal. SR 3.7.7.3 Verify each CCW pump starts automatically on an actual or simulated actuation signal. - FREQUENCY k8] months 5 CEOG STS Rev. 3.0, 03/31/04 SURVEILLANCE REQUIREMENTS SURVEILLANCE CCW System 3.7.7 FREQUENCY SR 3.7.7.1 SR 3.7.7.2 SR 3.7.7.3 CEOG STS-------------------------------NOTE------------------------.-----
Isolation of CCW flow to individual components does not render the CCW System inoperable.
Verify each CCW manual, power operated, and automatic valve in the flow path servicing safety related equipment, that is not locked, sealed, or otherwise secured in position, is in the correct position.Verify each CCW automatic valve in the flow path that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.Verify each CCW pump starts automatically on an actual or simulated actuation signal.3.7.7-2 lE 8]months Rev.3.0, 03/31/04 SWS 3.7.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.7.8.1 ...............................
NOTE Isolation of SWS flow to individual components does not render the SWS inoperable. Verify each SWS manual, power operated, and automatic valve in the flow path servicing safety related equipment, that is not locked, sealed, or otherwise secured in position, is in the correct position.
SR 3.7.8.2 Verify each SWS automatic valve in the flow path that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal. SR 3.7.8.3 Verify each SWS pump starts automatically on an actual or simulated actuation signal.
FREQUENCY - 31 days % - 4 [I 81 months +-, - [18] months +,, - CEOG STS Rev. 3.0, 03/31/04 SURVEILLANCE REQUIREMENTS SURVEILLANCE SWS 3.7.8 FREQUENCY SR 3.7.8.1 SR 3.7.8.2 SR 3.7.8.3 CEOG STS-------------------------------NOTE-----------------------------
Isolation of SWS flow to individual components does not render the SWS inoperable.
Verify each SWS manual, power operated, and automatic valve in the flow path servicing safety related equipment, that is not locked, sealed, or otherwise secured in position, is in the correct position.Verify each SWS automatic valve in the flow path that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.Verify each SWS pump starts automatically on an actual or simulated actuation signal.3.7.8-2 ill 8]months?-t (Tnse.rti)
Rev.3.0, 03/31/04 UHS 3.7.9 SURVEILLANCE REQUIREMENTS
* - - I - SURVEILLANCE I FREQUENCY SR 3.7.9.1 level]. CEOG STS Rev. 3.0, 03/31/04 SURVEILLANCE REQUIREMENTS SURVEILLANCE UHS 3.7.9 FREQUENCY SR 3.7.9.1 SR 3.7.9.2 SR 3.7.9.3 CEOG STS[Verify water level of UHS is 2[562]ft[mean sea levell*[Verify average water temperature of UHS is[90]OF.[Operate each cooling tower fan for 2[15]minutes.3.7.9-2 Rev.3.0, 03/31/04 ECW 3.7.10 3.7 PLANT SYSTEMS 3.7.10 Essential Chilled Water (ECW)
LC0 3.7.10 [Two] ECW trains shall be OPERABLE. APPLICABILITY: MODES 1, 2, 3, and 4. ACTIONS CONDITION A. One ECW train inoperable. B. Required Action and associated Completion Time not met. REQUIRED ACTION A.l Restore ECW train to OPERABLE status.
B.l Be in MODE 3. AND *3.2 Be in MODE 5. COMPLETION TIME 7 days 6 hours 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.10.1 ...............................
NOTE ..............................
Isolation of ECW flow to individual components does not render the ECW System inoperable. Verify each ECW 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.
CEOG STS Rev. 3.0, 03/31/04 3.7 PLANT SYSTEMS ECW 3.7.10 3.7.10 Essential Chilled Water (ECW)LCO 3.7.10 APPLICABILITY:
ACTIONS[Two]ECW trains shall be OPERABLE.MODES 1, 2, 3, and 4.CONDITION REQUIRED ACTION COMPLETION TIME A.One ECW train A.1 Restore ECW train to 7 days inoperable.
OPERABLE status...
,., B.Required Action and B.1 Be in MODE 3.6 hours associated Completion Time not met.AND B.2 Be in MODE 5.36 hours SURVEILLANCE REQUIREMENTS SR 3.7.10.1 CEOG STS SURVEILLANCE
-------------------------------
NOT E Isolation of ECW flow to individual components does not render the ECW System inoperable.
Verify each ECW 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.3.7.10-1 FREQUENCY Rev.3.0, 03/31/04 ECW 3.7.10 SURVEILLANCE REQUIREMENTS (continued)
CEOG STS SURVEILLANCE SR 3.7.10.2 Verify the proper actuation of each ECW System component on an actual or simulated actuation signal. Rev. 3.0, 03/31/04 FREQUENCY
@8] months e. SURVEILLANCE ECW 3.7.10 FREQUENCY SR 3.7.10.2 CEOG STS Verify the proper actuation of each ECW System component on an actual or simulated actuation signal.3.7.10-2 Rev.3.0, 03/31/04 CREACS 3.7.1 1 ACTIONS (continued)
CONDITION
-- D. Required Action and associated Completion Time of Condition A not met [in MODES 5 and 6, or] during movement of [recently] irradiated fuel assemblies.
E. Two CREACS trains inoperable [in MODES 5 and 6, or] during movement of [recently] irradiated fuel assemblies.
F. Two CREACS trains inoperable in MODE 1, 2,3, or 4 for reasons other than Condition B. REQUIRED ACTION D. 1 ---------------NOTE
--------------
Place in toxic gas protection mode if automatic transfer to toxic gas mode inoperable. Place OPERABLE CREACS train in emergency radiation protection mode.
D.2 Suspend movement of [recently] irradiated fuel assemblies.
E.l Suspend movement of [recently] irradiated fuel assemblies.
F.l Enter LC0 3.0.3. - COMPLETION TIME Immediately lmmediately lmmediately SURVEILLANCE REQUIREMENTS SURVEILLANCE I FREQUENCY I SR 3.7.11.1 Operate each CREACS train for
[_> 10 continuous hours with heaters operating or (for systems without heaters) 2 I5 minutes].
t!Xd 1 CEOG STS 3.7.1 1-2 Rev. 3.0, 03/31/04 CREACS 3.7.11 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME D.Required Action and D.1---------------
NOTE--------------
associated Completion Place in toxic gas Time of Condition A not protection mode if met[in MODES 5 and 6, automatic transfer to toxic or]during movement of gas mode inoperable.
[recently]
irradiated fuel------------------_
..._-_..........
-----------
assemblies.
Place OPERABLE Immediately CREACS train in emergency radiation protection mode.OR D.2 Suspend movement of Immediately
[recently]
irradiated fuel assemblies.
E.Two CREACS trains E.1 Suspend movement of Immediately inoperable
[in MODES 5[recently]
irradiated fuel and 6, or]during assemblies.
movement of[recently]
irradiated fuel assemblies.
F.Two CREACS trains F.1 Enter LCO 3.0.3.Immediately inoperable in MODE 1, 2, 3, or 4 for reasons other than Condition B.SURVEILLANCE REQUIREMENTS SR 3.7.11.1 CEOG STS SURVEILLANCE Operate each CREACS train for10 continuous hours with heaters operating or (for systems without heaters)15 minutes].3.7.11-2 FREQUENCY Rev.3.0, 03/31/04 CREACS 3.7.1 1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE SR 3.7.1 1.2 Perform required CREACS filter testing in accordance with [Ventilation Filter Testing Program (VFTP)]. SR 3.7.1 1.3 Verify each CREACS train actuates on an actual or simulated actuation signal.
SR 3.7.1 1.4 Verify one CREACS train can maintain a positive pressure of r [0.125] inches water gauge, relative to the adjacent [area] during the emergency radiation state of the emergency mode of operation at a emergency ventilation flow rate of 5 [3000] cfm. CEOG STS FREQUENCY In accordance with the [VFTP]
: z. 1181 months 4-. - 11 81 months on a STAGGERED c~-~ TEST BASIS 1 Rev. 3.0, 03131104 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE CREACS 3.7.11 FREQUENCY SR 3.7.11.2 SR 3.7.11.3 SR 3.7.11.4 CEOG STS Perform required CREACS filter testing in accordance with[Ventilation Filter Testing Program (VFTP)].Verify each CREACS train actuates on an actual or simulated actuation signal.Verify one CREACS train can maintain a positive pressure of 2:[0.125}inches water gauge, relative to the adjacent[area]during the emergency radiation state of the emergency mode of operation at a emergency ventilation flow rate of$[3000}cfm.3.7.11-3 In accordance with the[VFTP][[18]months on a STAGGERED-<TEST BASIS.
Rev.3.0, 03/31/04 CREATCS 3.7.12 ACTIONS (continued) COMPLETION TIME Immediately CONDITION E. Two CREATCS trains inoperable in MODE 1, 2, 3, or 4. SURVEILLANCE REQUIREMENTS SURVEILLANCE REQUIRED ACTION E.l Enter LC0 3.0.3. SR 3.7.72.1 Verify each CREATCS train has the capability to remove the assumed heat load. CEOG STS FREQUENCY Rev. 3.0, 03/31/04 ACTIONS (continued)
CONDITION E.Two CREATCS trains inoperable in MODE 1, 2,3,or4.E.1 REQUIRED ACTION Enter LCO 3.0.3.CREATCS 3.7.12 COMPLETION TIME Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.12.1 CEOG STS Verify each CREATCS train has the capability to remove the assumed heat load.3.7.12-2 Rev.3.0, 03/31/04 ECCS PREACS 3.7.13 SURVEILLANCE REQUIREMENTS - SURVEILLANCE SR 3.7.13.1 Operate each ECCS PREACS train for
[r 10 continuous hours with the heater operating or (for systems without heaters) 2 15 minutes]. SR 3.7.13.2 Perform required ECCS PREACS filter testing in accordance with the [Ventilation Filter Testing Program (VFTP)]. SR 3.7.13.3 Verify each ECCS PREACS train actuates on an actual or simulated actuation signal. SR 3.7.13.4 Verify one ECCS PREACS train can maintain a negative pressure 2 [ ] inches water gauge relative to atmospheric pressure during the [post accident]
mode of operation at a flow rate of 5 [20,000] cfm. SR 3.7.13.5 [ Verify each ECCS PREACS filter bypass damper can be opened. CEOG STS FREQUENCY In accordance with the [VFTP] [la] months on a c TAGGERED C, TEST BASIS 1 $7 k8] months ] Rev. 3.0, 03/31/04 SURVEILLANCE REQUIREMENTS SURVEILLANCE ECCS PREACS 3.7.13 FREQUENCY SR 3.7.13.1 SR 3.7.13.2 SR 3.7.13.3 SR 3.7.13.4 SR 3.7.13.5 CEOG STS Operate each ECCS PREACS train for[2': 10 continuous hours with the heater operating or (for systems without heaters)2': 15 minutes].Perform required ECCS PREACS filter testing in accordance with the[Ventilation Filter Testing Program (VFTP)].Verify each ECCS PREACS train actuates on an actual or simulated actuation signal.Verify one ECCS PREACS train can maintain a negative pressure 2':[]inches water gauge relative to atmospheric pressure during the[post accident]mode of operation at a flow rate of::::;[20,OOO}cfm.[Verify each ECCS PREACS filter bypass damper can be opened.3.7.13-2 In accordance with the[VFTP]Rev.3.0, 03/31/04 FBACS 3.7.14 ACTIONS (continued)
CONDITION C. [ Required Action and associated Completion Time of Condition A or B not met in MODE 1, 2, 3, or 4. Two FBACS trains inoperable in MODE I, 2, 3, or 4 for reasons other than Condition B. D. Required Action and Associated Completion Time [of Condition A]
not met during movement of [recently] irradiated fuel assemblies in the fuel building.
E. Two FBACS trains inoperable during movement of [recently]
irradiated fuel assemblies in the fuel building. REQUIRED ACTION C.l Be in MODE 3. AND - C.2 Be in MODE 5. D.l Place OPERABLE FBACS train in operation.
D.2 Suspend movement of [recently] irradiated fuel assemblies in the fuel building. SURVEILLANCE REQUIREMENTS E.l Suspend movement of [recently] irradiated fuel assemblies in the fuel building.
COMPLETION TIME 6 hours 36 hours ] lmmediately Immediately lmmediately - SURVEILLANCE 1 FREQUENCY SR 3.7.14.1 Operate each FBACS train for
[> 10 continuous El days hours with the heaters operating or (for systems without heaters) 2 I5 minutes].
CEOG STS 3.7.14-2 Rev. 3.0, 03/31/04 FBACS 3.7.14 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME C.[Required Action and C.1 Be in MODE 3.6 hours associated Completion Time of Condition A or B AND not met in MODE 1, 2, 3, or4.C.2 Be in MODE 5.36 hours]OR Two FBACS trains inoperable in MODE 1, 2, 3, or 4 for reasons other than Condition B.D.Required Action and D.1 Place OPERABLE FBACS Immediately Associated Completion train in operation.
Time[of Condition A]not met during movement of OR[recently]
irradiated fuel assemblies in the fuel D.2 Suspend movement of Immediately building.[recently]
irradiated fuel assemblies in the fuel building.E.Two FBACS trains E.1 Suspend movement of Immediately inoperable during[recently]
irradiated fuel movement of[recently]
assemblies in the fuel irradiated fuel building.assemblies in the fuel building._...0_-SURVEILLANCE REQUIREMENTS SR 3.7,14.1 CEOG STS SURVEILLANCE Operate each FBACS train for10 continuous hours with the heaters operating or (for systems without heaters)15 minutes].3,7.14-2 FREQUENCY@"1daYsb-Rev.3.0, 03/31/04 FBACS 3.7.14 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE SR 3.7.14.2 Perform required FBACS filter testing in accordance with the [Ventilation Filter Testing Program (VFTP)]. SR 3.7.14.3 [ Verify each FBACS train actuates on an actual or simulated actuation signal.
SR 3.7.14.4 Verify one FBACS train can maintain a negative pressure 2 [ ] inches water gauge with respect to atmospheric pressure, during the [post accident] mode of operation at a flow rate S [3000] cfm. SR 3.7.14.5 [ Verify each FBACS filter bypass damper can be opened. CEOG STS FREQUENCY In accordance with the [VFTP]
@8] months) k18] months on a STAGGERED TEST BASIS f. - \ Rev. 3.0, 03/31/04 FBACS 3.7.14 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY SR 3.7.14.2 Perform required FBACS filter testing in accordance with the[Ventilation Filter Testing Program (VFTP)].In accordance with the[VFTP]SR 3.7.14.3[Verify each FBACS train actuates on an actual or simulated actuation signal.Verify one FBACS train can maintain a negative pressure;;:.:[]inches water gauge with respect to atmospheric pressure, during the[post accident]mode of operation at a flow rate:-s;[3000J cfm.SR 3.7.14.5 SR 3.7.14.4 1J18l months on a STAGGERED<., TEST........
,,--.[Verify each FBACS filter bypass damper can be\Ii 8]months]')opened-T 1ln1'1
....
***
CEOG STS 3.7.14-3 Rev.3.0, 03/31/04 PREACS 3.7.15 3.7 PLANT SYSTEMS 3.7.15 Penetration Room Exhaust Air Cleanup System (PREACS) LC0 3.7.15 Two PREACS trains shall be OPERABLE.
APPLICABILITY:
MODES 1, 2,3, and 4. ACTIONS CONDITION A. One PREACS train inoperable.
B. Two PREACS trains inoperable due to inoperable penetration room boundary.
C. Required Action and associated Completion Time not met. -- REQUIRED ACTION A.1 Restore PREACS train to OPERABLE status.
B.1 Restore penetration room boundary to OPERABLE status. - .. C.1 Be in MODE 3. C.2 Be in MODE 5. SURVEILLANCE REQUIREMENTS COMPLETION TIME 7 days 24 hours 6 hours 36 hours - SURVEILLANCE I FREQUENCY CEOG STS 3.7.15-1 Rev. 3.0, 03/31/04 .- - SR 3.7.15.1 Operate each PREACS train for [2 10 continuous hours with the heater operating or (for systems without heaters) 2 15 minutes]. - El days PREACS 3.7.15 3.7 PLANT SYSTEMS 3.7.15 Penetration Room Exhaust Air Cleanup System (PREACS)LCO 3.7.15 APPLICABILITY:
ACTIONS Two PREACS trains shall be OPERABLE.---------------------------------------------
NOT E--------------------------------------------
The penetration room boundary may be opened intermittently under administrative control.MODES 1,2,3, and 4.CONDITION REQUIRED ACTION COMPLETION TIME A.One PREACS train A.1 Restore PREACS train to 7 days inoperable.
OPERABLE status.B.Two PREACS trains B.1 Restore penetration room 24 hours inoperable due to boundary to OPERABLE inoperable penetration status.room boundary.
..C.Required Action and C.1 Be in MODE 3.6 hours associated Completion Time not met.AND Co2 Be in MODE 5.36 hours SURVEILLANCE REQUIREMENTS SR 3.7.15.1 CEOG STS SURVEILLANCE Operate each PREACS train for[2: 10 continuous hours with the heater operating or (for systems without heaters)2': 15 minutes].3.7.15-1 FREQUENCY[i1 days Rev.3.0, 03/31/04 PREACS 3.7.15 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE SR 3.7.15.2 Verify required PREACS filter testing in accordance with the [Ventilation Filter Testing Program (VFTP)]. SR 3.7.15.3 [ Verify each PREACS train actuates on an actual or simulated actuation signal.
SR 3.7.15.4 [ Verify one PREACS train can maintain a negative pressure r [ ] inches water gauge with respect to atmospheric pressure during the [post accident]
mode of operation at a flow rate of 2 [3000] cfm. SR 3.7.15.5 [ Verify each PREACS filter bypass damper can be opened. FREQUENCY In accordance with the [VFTP]
4') lfi8] months 1 , 381 months on a CEOG STS Rev. 3.0, 03/31/04 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE PREACS 3.7.15 FREQUENCY SR 3.7.15.2 SR 3.7.15.3 SR 3.7.15.4 SR 3.7.15.5 CEOG STS Verify required PREACS filter testing in accordance with the[Ventilation Filter Testing Program (VFTP)J.[Verify each PREACS train actuates on an actual or simulated actuation signal.[Verify one PREACS train can maintain a negative pressure:::::[J inches water gauge with respect to atmospheric pressure during the[post accidentJ mode of operation at a flow rate of[3000]cfm.[Verify each PREACS filter bypass damper can be opened.In accordance with the[VFTPJ..c" ID.8]months J 1 L:::.-_l(,'-1.
Rev.3.0, 03/31/04 Fuel Storage Pool Water Level 3.7.16 3.7 PLANT SYSTEMS 3.7.16 Fuel Storage Pool Water Level LC0 3.7.16 The fuel storage pool water level shall be 2 23 17 over the top of irradiated fuel assemblies seated in the storage racks. APPLICABILITY:
During movement of irradiated fuel assemblies in the fuel storage pool. ACTIONS - - I CONDITION I REQUIRED ACTION / COMPLETION TIME A. Fuel storage pool water level not within limit. SURVEILLANCE REQUIREMENTS A.1 ---------------
NOTE --------------
LC0 3.0.3 is not applicable.
Suspend movement of irradiated fuel assemblies in fuel storage pool. SURVEILLANCE ( FREQUENCY Immediately CEOG STS SR 3.7.16.1 Verify the fuel storage pool water level is 2 23 ft above the top of irradiated fuel assemblies seated in the storage racks. Rev. 3.0, 03/31/04 Fdays 2r\Se.tT]
Fuel Storage Pool Water Level 3.7.16 3.7 PLANT SYSTEMS 3.7.16 Fuel Storage Pool Water Level LCO 3.7.16 APPLICABILITY:
ACTIONS The fuel storage pool water level shall be23 ft over the top of irradiated fuel assemblies seated in the storage racks.During movement of irradiated fuel assemblies in the fuel storage pool.CONDITION A.Fuel storage pool water A.1 level not within limit.REQUIRED ACTION---------------N 0 TE--------------
LCO 3.0.3 is not applicable.
COMPLETION TIME SURVEILLANCE REQUIREMENTS Suspend movement of Immediately irradiated fuel assemblies in fuel storage pool.SR 3.7.16.1 CEOG STS SURVEILLANCE Verify the fuel storage pool water level is::0>: 23 ft above the top of irradiated fuel assemblies seated in the storage racks.3.7.16-1 FREQUENCYRev.3.0, 03/31/04 Fuel Storage Pool Boron Concentration 3.7.17 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.17.1 within limit. CEOG STS Rev. 3.0, 03/31/04 Fuel Storage Pool Boron Concentration 3.7.17 SURVEILLANCE REQUIREMENTS SR 3.7.17.1 CEOG STS SURVEILLANCE Verify the fuel storage pool boron concentration is within limit 3.7.17-2 FREQUENCY Rev.3.0, 03/31/04 Secondary Specific Activity 3.7.1 9 3.7 PLANT SYSTEMS 3.7.1 9 Secondary Specific Activity LC0 3.7.19 The specific activity of the secondary coolant shall be I [0.10] pCi1gm DOSE EQUIVALENT 1-1 31. APPLICABILITY:
MODES 1, 2, 3, and 4. ACTIONS CONDITION A. Specific activity not within limit. REQUIRED ACTION COMPLETION TIME A.l Be in MODE 3. AND A.2 Be in MODE 5. 6 hours 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE I FREQUENCY SR 3.7.19.1 Verify the specific activity of the secondary coolant is within limit. CEOG STS Rev. 3.0, 03/31/04 Secondary Specific Activity 3.7.19 3.7 PLANT SYSTEMS 3.7.19 Secondary Specific Activity LCO 3.7.19 APPLICABILITY:
ACTIONS The specific activity of the secondary coolant shall be[0.10]llCilgm DOSE EQUIVALENT MODES 1, 2, 3, and 4.CONDITION A.Specific activity not within limit.A.1 AND A.2 REQUIRED ACTION Be in MODE 3.Be in MODE 5.COMPLETION TIME 6 hours 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.19.1 CEOG STS Verify the specific activity of the secondary coolant is within limit.3.7.19-1 Rev.3.0, 03/31/04 AC Sources - Operating ACTIONS (continued)
CONDITION F. ----------
-- NOTE ------------
[ This Condition may be deleted if the unit design is such that any sequencer failure mode will only affect the ability of the associated DG to power its respective safety loads following a loss of offsite power independent of, or coincident with, a Design Basis Event.
---------------*-----------------
One [required] [automatic load sequencer] inoperable.
G. Required Action and associated Completion Time of Condition A, 6, C, D, E, or [F] not met. H. Three or more [required]
AC sources inoperable. REQUIRED ACTION F.l Restore [required] [automatic load sequencer]
to OPERABLE status.
G.l Be in MODE 3. AND - G.2 Be in MODE 5. H.l Enter LC0 3.0.3. SURVEILLANCE REQUIREMENTS COMPLETION TIME [I 21 hours ] 6 hours 36 hours Immediately SURVEILLANCE - FREQUENCY SR 3.8.1.1 Verify correct breaker alignment and indicated power availability for each [required]
offsite circuit. CEOG STS Rev. 3.1, 12/01/05 AC Sources-Operating 3.8.1 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME F.------------N OTE------------
F.1 Restore[required]
[12]hours][This Condition may be[automatic load sequencer]
deleted if the unit design to OPERABLE status.is such that any sequencer failure mode will only affect the ability of the associated DG to power its respective safety loads following a loss of offsite power independent of, or coincident with, a Design Basis Event.-..._------------
..._------------
...---One[required]
[automatic load sequencer]
inoperable.
G.Required Action and G.1 Be in MODE 3.6 hours associated Completion Time of Condition A, B, AND C, D, E, or[F]not met.G.2 Be in MODE 5.36 hours H.Three or more[required]
H.1 Enter LCO 3.0.3.Immediately AC sources inoperable.
SURVEILLANCE REQUIREMENTS SR 3.8.1.1 CEOG STS SURVEILLANCE Verify correct breaker alignment and indicated power availability for each[required]
offsite circuit.FREQUENCY Rev.3.1,12/01/05 AC Sources - Operating SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE SR 3.8.1.2 ..............................
NOTES we---------------------------
: 1. All DG starts may be preceded by an engine prelube period and followed by a warmup period prior to loading. 2. [ A modified DG start involving idling and gradual acceleration to synchronous speed may be used for this SR as recommended by the manufacturer. When modified start procedures are not used, the time, voltage, and frequency tolerances of SR 3.8.1.7 must be met. ] Verify each DG starts from standby conditions and achieves steady state voltage 2 [3740] V and I [4580] V, and frequency 2 [58.8] Hz and r [61.2] Hz. SR 3.8.1.3 -------------------------+----
NOTES-----------------------------
: 1. DG loadings may include gradual loading as recommended by the manufacturer.
: 2. Momentary transients outside the load range do not invalidate this test. 3. This Surveillance shall be conducted on only one DG at a time. 4. This SR shall be preceded by and immediately follow without shutdown a successful performance of SR 3.8.1.2 or SR 3.8.1.7. Verify each DG is synchronized and loaded, and operates for 2 60 minutes at a load 2 145001 kW and 5 [5000] kW. SR 3.8.1.4 Verify each day tank [and engine mounted tank] contains 2 [220] gal of fuel oil. CEOG STS FREQUENCY Rev. 3.1, 12/01/05 AC Sources-Operating 3,8,1 SURVEILLANCE REQUIREMENTS (continued)
SR 3.8,1.2 SR 3,8.1.3 SR 3,8.1.4 CEOG STS SURVEILLANCE 1.All DG starts may be preceded by an engine prelube period and followed by a warmup period prior to loading.2.[A modified DG start involving idling and gradual acceleration to synchronous speed may be used for this SR as recommended by the manufacturer.
When modified start procedures are not used, the time, voltage, and frequency tolerances of SR 3,8,1,7 must be met]Verify each DG starts from standby conditions and achieves steady state voltage;::O:
[3740]Vand:e::;[4580]V, and frequency;::0:[58.8]Hz and:e::;[61.2]Hz, NOTES 1, DG loadings may include gradual loading as recommended by the manufacturer.
2, Momentary transients outside the load range do not invalidate this test.3, This Surveillance shall be conducted on only one DG at a time.4.This SR shall be preceded by and immediately follow without shutdown a successful performance of SR 3,8.1.2 or SR 3,8,1,7, Verify each DG is synchronized and loaded, and operates for;::0: 60 minutes at a load;::0:[4500]kW and[5000]kW, Verify each day tank[and engine mounted tank]contains;::0:[220]gal of fuel oiL 3.8,1-5 FREQUENCY(inSe.r t1)Rev, 3.1,12/01/05 AC Sources - Operating
 
====3.8.1 SURVEILLANCE====
REQUIREMENTS (continued)
SURVEILLANCE SR 3.8.1.5 Check for and remove accumulated water from each day tank [and engine mounted tank]. SR 3.8.1.6 Verify the fuel oil transfer system operates to [automatically] transfer fuel oil from storage tank[s] to the day tank [and engine mounted tank].
SR 3.8.1.7 ...............................
NOTE ..............................
All DG starts may be preceded by an engine prelube period. Verify each DG starts from standby condition and achieves:
: a. In I [lo] seconds, voltage L [3740] V and frequency 2 [58.8] Hz and b. Steady state voltage r [3740] V and I [4580] V, and frequency 2 [58.8] Hz and r [61.2] Hz. SR 3.8.1.8 ...............................
NOTE --------------------------+---
[ This Surveillance shall not normally be performed in MODE 1 or 2. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. ] ----*---------+---------+--------------------------------------------
[ Verify [automatic [and] manual] transfer of AC power sources from the normal offsite circuit to each alternate [required]
offsite circuit. FREQUENCY 184 days 51 CEOG STS Rev. 3.1, 12/01/05 AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE FREQUENCY Verify the fuel oil transfer system operates to[automatically}
transfer fuel oil from storage tank[s]to the day tank[and engine mounted tank].SR 3.8.1.6 SR 3.8.1.5 Check for and remove accumulated water from each[E1]daysday tank[and engine mounted tankJ.r:::;:::--
...
..>>[[92J days SR 3.8.1.7-------------------------------
NOT E------------------------------
All DG starts may be preceded by an engine prelube period.Verify each DG starts from standby condition and achieves: a.In[10]seconds, voltage 2':[3740J V and frequency 2':[58.8]Hz and b.Steady state voltage 2':[3740]V and[4580]V, and frequency 2':[58.8J Hz and[61.2J Hz.------------_
..__..
.._-_.-_.._-SR 3.8.1.8-------------------------------
NOT E------------------------------
.[This Surveillance shall not normally be performed in MODE 1 or 2.However,this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Credit may be taken for unplanned events that satisfy this SR.J[Verify[automatic
[and}manualJ transfer of AC power sources from the normal offsite circuit to each alternate[required}
offsite circuit.
_i________*.*,*__..........L
__*_CEOG STS 3.8.1-6 Rev.3.1,12/01/05 AC Sources - Operating SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE SR 3.8.1.9 ..............................
NOTES .............................
: 1. [ This Surveillance shall not normally be performed in MODE 1 or 2. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.
Credit may be taken for unplanned events that satisfy this SR. 2. If performed with the DG synchronized with offsite power, it shall be performed at a power factor I [0.9]. However, if grid conditions do not permit, the power factor limit is not required to be met. Under this condition the power factor shall be maintained as close to the limit as practicable.
] Verify each DG rejects a load greater than or equal to its associated single largest post-accident load and: a. Following load rejection, the frequency is 5 [63] Hz, b. Within [3] seconds following load rejection, the voltage is 2 [3740] V and s [4580] V, and c. Within [3] seconds following load rejection, the frequency is r [58.8] Hz and I [61.2] Hz. FREQUENCY C [18] months 4--, - CEOG STS Rev. 3.1, 12/01/05 SURVEILLANCE AC Sources-Operating 3.8.1 FREQUENCY SR 3.8.1.9 CEOG STS------------------------------
NOTES-----------------------------
1.[This Surveillance shall not normally be performed in MODE 1 or 2.However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Credit may be taken for unplanned events that satisfy this SR.2.If performed with the DG synchronized with offsite power, it shall be performed at a power factor[0.9].However, if grid conditions do not permit, the power factor limit is not required to be met.Under this condition the power factor shall be maintained as close to the limit as practicable.
]Verify each DG rejects a road greater than or equal to its associated single largest post-accident load and: a.Following load rejection, the frequency is[63]Hz, b.Within[3]seconds follOWing load rejection, the voltage is 2[3740)V and:-0;[4580]V, and c.Within[3)seconds following load rejection, the frequency is 2[58.8]Hz and:-o;[61.2J Hz.3.8.1-7 Rev.3.1,12/01/05 AC Sources - Operating SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE SR 3.8.1.10 .............................
NOTES .............................
I. [ This Surveillance shall not normally be performed in MODE 1 or 2. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.
Credit may be taken for unplanned events that satisfy this SR. 2. If performed with DG synchronized with offsite power, it shall be performed at a power factor I [0.9]. However, if grid conditions do not permit, the power factor limit is not required to be met. Under this condition the power factor shall be maintained as close to the limit as practicable.
] --------*-----------------F------------------------------"-------w--
Verify each OG does not trip, and voltage is maintained I [5000] V during and following a load rejection of 2 [4500] kW and r [5000] kW. FREQUENCY CEOG STS Rev. 3.1, 12/01/05 SURVEILLANCE AC Sources-Operating 3.8.1 FREQUENCY SR 3.8.1.10 CEOG STS-----------------------------N OTE S-----------------------------
1.[This Surveillance shall not normally be performed in MODE 1 or 2.However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Credit may be taken for unplanned events that satisfy this SR.2.If performed with DG synchronized with offsite power, it shall be performed at a power factor s[0.9].However, if grid conditions do not permit.the power factor limit is not required to be met.Under this condition the power factor shall be maintained as close to the limit as practicable.
]Verify each DG does not trip, and voltage;s maintained s[5000]V during and following a load rejection of;::C[4500]kW and s[5000]kW.3.8.1-8 Rev.3.1, 12/01/05 AC Sources - Operating SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE SR 3.8.1.11 -*----------------------------
NOTES -----------------..
-----------
I. All DG starts may be preceded by an engine prelu be period. 2. This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. ----*--------------------------------*---------------+*-------------- Verify on an actual or simulated loss of offsite power signal: a. De-energization of emergency buses, b. Load shedding from emergency buses, c. DG auto-starts from standby condition and: 1. Energizes permanently connected loads in I [lo] seconds, 2. Energizes auto-connected shutdown loads through [automatic load sequencer], 3. Maintains steady state voltage 2 [3740] V and s I45801 V, 4. Maintains steady state frequency 2 [58.8] Hz and < L61.21 Hz, and 5. Supplies permanently connected [and auto-connected] shutdown loads for r 5 minutes. FREQUENCY
[I81 months fi - CEOG STS Rev. 3.1, 12/01/05 AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS SR 3.8.1.11 CEOG STS SURVEILLANCE
------------------------------NOTES-----------------------------
1.All DG starts may be preceded by an engine prelube period.2.This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4.However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Credit may be taken for unplanned events that satisfy this SR.Verify on an actual or simulated loss of offsite power signal: a.De-energization of emergency buses, b.Load shedding from emergency buses, c.DG auto-starts from standby condition and: 1.Energizes permanently connected loads in 5[10]seconds, 2.Energizes auto-connected shutdown loads through[automatic load sequencer], 3.Maintains steady state voltage;:0::[3740]V and 5[4580]V, 4.Maintains steady state frequency;::::[58.8]Hz and 5[61.2]Hz, and 5.Supplies permanently connected[and auto-connected]
shutdown loads for;:::: 5 minutes.3.8.1-9 FREQUENCYRev.3.1, 12/01/05 AC Sources - Operating SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE
: 2. This Surveillance shall not normally be performed in MODE 1 or 2. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. Verify on an actual or simulated Engineered Safety Feature (ESF) actuation signal each DG auto-starts from standby condition and: a. In 5 [lo] seconds after auto-start and during tests, achieves voltage 2 [3740] V and frequency r [58.8] Hz, b. Achieves steady state voltage 2 [3740] V and 2 [4580] V and frequency 2 [58.8] Hz and 5 [61.2] Hz, c. Operates for 2 5 minutes, d. Permanently connected loads remain energized from the offsite power system, and
: e. Emergency loads are energized
[or auto- connected through the automatic load sequencer] from the offsite power system.
CEOG STS FREQUENCY Rev. 3.1, 12/01/05 SURVEILLANCE AC Sources-Operating 3.8.1 FREQUENCY SR 3.8.1.12 CEOG STS------------------------------
NOT E S-----------------------------
1.[All DG starts may be preceded by an engine prelube period.2.This Surveillance shall not normally be performed in MODE 1 or 2.However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Credit may be taken for unplanned events that satisfy this SR.Verify on an actual or simulated Engineered Safety Feature (ESF)actuation signal each DG auto-starts from standby condition and: a.In S;[10]seconds after auto-start and during tests, achieves voltage[3740]Vand frequency;:::
[58.8]Hz, b.Achieves steady state voltage;:::
[3740]V and S;[4580]V and frequency;:::
[58.8]Hz and$[61.2]Hz, c.Operates for5 minutes, d.Permanently connected loads remain energized from the offsite power system, and e.Emergency loads are energized[orconnected through the automatic load sequencer]
from the offsite power system.3.8.1-10[!!81 Rev.3.1,12/01/05 AC Sources - Operating
 
====3.8.1 SURVEILLANCE====
REQUIREMENTS (continued)
SURVEILLANCE SR 3.8.1.13 ...............................
NOTE ..............................
[ This Surveillance shall not normally be performed in MODE 1 or 2. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. ] Verify each DG's noncritical automatic trips are bypassed on [actual or simulated loss of voltage signal on the emergency bus concurrent with an actual or simulated ESF actuation signal]. FREQUENCY CEOG STS Rev. 3.1. 12/01/05 SURVEILLANCE AC Sources-Operating 3.8.1 FREQUENCY SR 3.8.1.13 CEOG STS-------------------------------NOTE------------------------------
[This Surveillance shall not normally be performed in MODE 1 or 2.However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Credit may be taken for unplanned events that satisfy this SR.]Verify each DG's noncritical automatic trips are bypassed on[actual or simulated loss of voltage signal on the emergency bus concurrent with an actual or simulated ESF actuation signal].3.8.1-11 Ci&#xa3;\serill Rev.3.1,12/01/05 AC Sources - Operating SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE SR 3.8.1.14 ..............................
NOTES .............................
: 1. Momentary transients outside the load and power factor ranges do not invalidate this test.
: 2. This Surveillance shall not normally be performed in MODE 1 or 2. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR.
: 3. If performed with DG synchronized with offsite power, it shall be performed at a power factor 5 [0.9]. However, if grid conditions do not permit, the power factor limit is not required to be met. Under this condition the power factor shall be maintained as close to the limit as practicable. Verify each DG operates for 2 24 hours: a. For 2 [2] hours loaded 2 [5250] kW and 5 [5500] kW and b. For the remaining hours of the test loaded 2 [4500] kW and 5 [5000] kW. CEOG STS FREQUENCY b8] months Rev. 3.1, 12/01/05 SURVEILLANCE AC Sources-Operating 3.8.1 FREQUENCY SR 3.8.1.14 CEOG STS------------------------------NOTES-----------------------------
1.Momentary transients outside the load and power factor ranges do not invalidate this test.2.This Surveillance shall not normally be performed in MODE 1 or 2.However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Credit may be taken for unplanned events that satisfy this SR.3.If performed with DG synchronized with offsite power, it shall be performed at a power factor:5[0.9].However, if grid conditions do not permit, the power factor limit is not required to be met.Under this condition the power factor shall be maintained as close to the limit as practicable.
Verify each DG operates for 2: 24 hours: a.For<::[2]hours loaded<::[5250]kW and:5[5500]kW and b.For the remaining hours of the test loaded<::[4500]kW and:5[5000]kW.3.8.1-12 Rev.3.1,12/01/05 AC Sources - Operating
 
====3.8.1 SURVEILLANCE====
REQUIREMENTS (continued)
SURVEILLANCE SR 3.8.1.15 ..............................
NOTES ...........................
: 1. This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated 2 [2] hours loaded 2 [4500] kW and 5 [5000] kW. Momentary transients outside of load range do not invalidate this test. 2. All DG starts may be preceded by an engine prelube period. Verify each DG starts and achieves:
: a. In I [lo] seconds, voltage 2 [3740] V and frequency 2 [58.8] Hz and b. Steady state voltage 2 [3740] V and I [4580] V, and frequency 2 [58.8] Hz and 2 [61.2] Hz. SR 3.8.1.16 ...............................
NOTE ..............................
This Surveillance shall not normally be performed in MODE 1,2, 3, or 4. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. Verify each DG: a. Synchronizes with offsite power source while loaded with emergency loads upon a simulated restoration of offsite power, b. Transfers loads to offsite power source, and
: c. Returns to ready-to-load operation.
FREQUENCY 4 [18] months 6 m X [18] months f CEOG STS Rev. 3.1, 12/01/05 AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SR 3.8.1.15 SR 3.8.1.16 CEOG STS SURVEILLANCE
------------------------------NOTES-----------------------------
1.This SUNeillance shall be performed within 5 minutes of shutting down the DG after the DG has operated:::>:
[2J hours loaded:::>:
[4500J kW and:s;[5000J kW.Momentary transients outside of load range do not invalidate this test.2.All DG starts may be preceded by an engine prelube period.Verify each DG starts and achieves: a.In[10J seconds, voltage:::>:
[3740J V and frequency:::>:
[58.8J Hz and b.Steady state voltage:::>:
[3740J V and[4580J V, and frequency:::>:
[58.8J Hz and:s;[61.2J Hz.-------------------------------
NOT E------------------------------
This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4.However, this SUNeillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Credit may be taken for unplanned events that satisfy this SR.Verify each DG: a.Synchronizes with offsite power source while loaded with emergency loads upon a simulated restoration of offsite power, b.Transfers loads to offsite power source, and c.Returns to ready-to-Ioad operation.
3.8.1-13 FREQUENCY 1...-[18J months Rev.3.1,12/01/05 AC Sources - Operating
 
====3.8.1 SURVEILLANCE====
REQUIREMENTS (continued)
SURVEILLANCE I FREQUENCY SR 3.8.1.17 .............................
NOTE ..............................
[ This Surveillance shall not normally be performed in MODE I, 2, 3, or 4. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.
Credit may be taken for unplanned events that satisfy this SR. Verify, with a DG operating in test mode and connected to its bus, an actual or simulated ESF actuation signal overrides the test mode by:
: a. Returning DG to ready-to-load operation and I [ b. Automatically energizing the emergency load from offsite power. ] "7 months ] SR 3.8.1.18 ...............................
NOTE ..............................
[ This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. ] Verify interval between each sequenced load block is within
+ [lo% of design interval] for each emergency [and shutdown] load sequencer.
monthsf -,-1, CEOG STS Rev. 3.1, 12/01/05 AC Sources-Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)
SR 3.8.1.17 SR 3.8.1.18 CEOG STS SURVEILLANCE
-----------------------------
NOTE--------------------.----.----
[This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4.However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Credit may be taken for unplanned events that satisfy this SR.Verify, with a DG operating in test mode and connected to its bus, an actual or simulated ESF actuation signal overrides the test mode by: a.Returning DG to ready-to-Ioad operation and[b.Automatically energizing the emergency load from offsite power.]-------.--------------------.--
NOT E------------------------------
[This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4.However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Credit may be taken for unplanned events that satisfy this SR.]Verify interval between each sequenced load block is within+/-[10%of design interval]for each emergency[and shutdown]load sequencer.
3.8.1-14 FREQUENCY Rev.3.1, 12/01/05 AC Sources - Operating 3.8.1 2. This Surveillance shall not normally be performed in MODE 1,2, 3, or 4. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. --------------*--------------------*-*------------------------------- SURVEILLANCE REQUIREMENTS (continued)
Verify on an actual or simulated loss of offsite power signal in conjunction with an actual or simulated ESF actuation signal: - SURVEILLANCE a. De-energization of emergency buses, FREQUENCY
: b. Load shedding from emergency buses, c. DG auto-starts from standby condition and: 1. energizes permanently connected loads in 5 [lo] seconds, 2. energizes auto-connected emergency loads through [load sequencer], 3. achieves steady state voltage 2 [3740] V and I [4580] V, 4. achieves steady state frequency 2 [58.8] Hz and 5 [61.2] Hz, and 5. supplies permanently connected
[and auto-connected] emergency loads for 2 [5] minutes. months CEOG STS Rev. 3.1, 12/01/05 SURVEILLANCE AC Sources-Operating 3.8.1 FREQUENCY SR 3.8.1.19--------------**-------------NOTES-----------------------------
1.All DG starts may be preceded by an engine prelube period.2.This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4.However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Credit may be taken for unplanned events that satisfy this SR.Verify on an actual or simulated loss of offsite power WB]months__",--_.....-_
signal in conjunction with an actual or simulated j)ESF actuation signal: a.De-energization of emergency buses, b.Load shedding from emergency buses, c.DG auto-starts from standby condition and: 1.energizes permanently connected loads in s[10]seconds, 2.energizes auto-connected emergency loads through[load sequencer], 3.achieves steady state voltage 2[3740]V and s[4580]V, 4.achieves steady state frequency 2:[58.8]Hz and s[61.2]Hz, and 5.supplies permanently connected[and auto-connected]
emergency loads for[5]minutes.CEOG STS 3.8.1-15 Rev.3.1,12/01/05 AC Sources - Operating
 
====3.8.1 SURVEILLANCE====
REQUIREMENTS (continued)
SURVEILLANCE SR 3.8.1.20 ...............................
NOTE ----------------------------
All DG starts may be preceded by an engine prelube period. ---------------------------------------*--"*"**-""*------------------
Verify, when started simultaneously from standby condition, each DG achieves:
: a. In < [lo] seconds, voltage 2 [3740] V and frequency 2 [58.8] Hz and b. Steady state voltage 2 [3740] V and I [4580] V, and frequency r 158.81 Hz and I [61.2] Hz. CEOG STS FREQUENCY 11 0 years - Rev. 3.1, 12/01/05 SURVEILLANCE AC Sources-Operating 3.8.1 FREQUENCY SR 3.8.1.20 CEOG STS-------------------------------NO TE----------------------------
All DG starts may be preceded by an engine prelube period.Verify, when started simultaneously from standby condition, each DG achieves: a.In:O::;[10]seconds, voltage 2::[3740]V and frequency 2::[58.8]Hz and b.Steady state voltage 2::[3740J V and:0::;[4580J V, and frequency:::::
[58.8)Hz and:0::;[61.2)Hz.3.8.1-16 Rev.3.1,12/01/05 Diesel Fuel Oil, Lube Oil, and Starting Air
 
====3.8.3 ACTIONS====
(continued)
.- CONDITION F. Required Action and associated Completion Time not met. One or more DGs with diesel fuel oil, lube oil, or starting air subsystem not within limits for reasons other than Condition A, B, C, D, or E. REQUIRED ACTION F.l Declare associated DG inoperable.
COMPLETION TIME Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.8.3.1 Verify each fuel oil storage tank contains 2 [33,000] gal of fuel. SR 3.8.3.2 Verify lubricating oil inventory is 2 [500] gal. SR 3.8.3.3 Verify fuel oil properties of new and stored fuel oil are tested in accordance with, and maintained within the limits of, the Diesel Fuel Oil Testing Program. SR 3.8.3.4 Verify each DG air start receiver pressure is 2 [225] psig. SR 3.8.3.5 Check for and remove accumulated water from each fuel oil storage tank. CEOG STS FREQUENCY 31 days In accordance with the Diesel Fuel Oil Testing Program [31] days f 7 -C ~nseFQ Rev. 3.0, 03/31/04 Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 ACTIONS (continued)
CONDITION F.Required Action and associated Completion Time not met.One or more DGs with diesel fuel oil, lube oil, or starting air subsystem not within limits for reasons other than Condition A, B, C, D, or E.F.1 REQUIRED ACTION Declare associated DG inoperable.
COMPLETION TIME Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.3.1 SR 3.8.3.2 SR 3.8.3.3 SR 3.8.3.4 Verify each fuel oil storage tank contains 2':[33,000]gal of fuel.Verify lubricating oil inventory is 2':[500]gal.Verify fuel oil properties of new and stored fuel oil are tested in accordance with, and maintained within the limits of, the Diesel Fuel Oil Testing Program.Verify each DG air start receiver pressure is 2':[225]psig.In accordance with the Diesel Fuel Oil Testing Program
__
SR 3.8.3.5 Check for and remove accumulated water from each W1]daysfuel oil storage tank.
CEOG STS 3.8.3-2 Rev.3.0, 03/31/04 DC Sources - Operating SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.8.4.1 Verify battery terminal voltage is greater than or equal to the minimum established float voltage.
SR 3.8.4.2 Verify each battery charger supplies 2 [400] amps at greater than or equal to the minimum'established float voltage for 2 [8] hours. Verify each battery charger can recharge the battery to the fully charged state within [24] hours while supplying the largest combined demands of the various continuous steady state loads, after a battery discharge to the bounding design basis event discharge state.
SR 3.8.4.3 ------------------------------NOTES
.............................
I. The modified performance discharge test in SR 3.8.6.6 may be performed in lieu of SR 3.8.4.3. 2. This Surveillance shall not normally be performed in MODE 1,2, 3, or 4. However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced. Credit may be taken for unplanned events that satisfy this SR. ----------------------*-------------------------------"--------------
Verify battery capacity is adequate to supply, and maintain in OPERABLE status, the required emergency loads for the design duty cycle when subjected to a battery service test.
FREQUENCY
*- 7 days / [18] months . - 1 [I 81 months %\ - CEOG STS Rev. 3.0, 03/31/04 DC Sources-Operating 3.8.4 SURVEILLANCE REQUIREMENTS SR 3.8.4.1 SR 3.8.4.2 SR 3.8.4.3 CEOG STS SURVEILLANCE Verify battery terminal voltage is greater than or equal to the minimum established float voltage.Verify each battery charger supplies;::c[400]amps at greater than or equal to the minimum'established float voltage for;::c[8]hours.Verify each battery charger can recharge the battery to the fully charged state within[24]hours while supplying the largest combined demands of the various continuous steady state loads, after a battery discharge to the bounding design basis event discharge state.------------------------------NOTES-----------------------------
1.The modified performance discharge test in SR 3.8.6.6 may be performed in lieu of SR 3.8.4.3.2.This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4.However, portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Credit may be taken for unplanned events that satisfy this SR.Verify battery capacity is adequate to supply, and maintain in OPERABLE status, the required emergency loads for the design duty cycle when subjected to a battery service test.3.8.4-2 FREQUENCY(TnSert 1.)Rev.3.0, 03/31/04 Battery Parameters
 
====3.8.6 ACTIONS====
(continued)
CONDITION F. Required Action and associated Completion Time of Condition A, B, C, D, or E not met.
One [or two] batter[y][ies on one train] with one or more battery cells float voltage 4 [2.07] V and float current
> [Z] amps. REQUIRED ACTION F.l Declare associated battery inoperable.
COMPLETION TIME Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.8.6.1 -------------------------------NOTE
-----------------------+------ Not required to be met when battery terminal voltage is less than the minimum established float voltage of SR 3.8.4.1. Verify each battery float current is < [2] amps. SR 3.8.6.2 Verify each battery pilot cell voltage is 2 [2.07] V SR 3.8.6.3 Verify each battery connected cell electrolyte level is greater than or equal to minimum established design limits.
SR 3.8.6.4 Verify each battery pilot cell temperature is greater than or equal to minimum established design limits. CEOG STS FREQUENCY I-- 31 days .c 31 days f-, 4 Rev. 3.0, 03/31/04 Battery Parameters
 
====3.8.6 ACTIONS====
(continued)
CONDITION F.Required Action and associated Completion Time of Condition A, B, C, D, or E not met.One[or two]batter[y][ies on one train]with one or more battery cells float voltage<[2.07]V and float current>[2]amps.F.1 REQUIRED ACTION Declare associated battery inoperable.
COMPLETION TIME Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.1 SR 3.8.6.2 SR 3.8.6.3-------------------------------NOTE-----------------------**-*---
Not required to be met when battery terminal voltage is lessthanthe minimum established float voltage of SR 3.8.4.1.Verify each battery float current is:-:::;[2]amps.Verify each battery pilot cell voltage is 2:[2.07]V.Verify each battery connected cell electrolyte level is greater than or equal to minimum established design limits.@days+---::::::.-----r"'_
SR 3.8.6.4 Verify each battery pilot cell temperature is greater________t_ha_n_or_e_q_u_a_1
_to_m_in_im_um_e
__
CEOG STS 3.8.6-3 Rev.3.0, 03/31/04 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE Battery Parameters
 
====3.8.6 FREQUENCY====
SR 3.8.6.5 SR 3.8.6.6 CEOG STS Verify each battery connected cell voltage is[2.07]V.-------------------------------
NOT E------------------------------
This Surveillance shall not be performed in MODE 1, 2, 3, or 4.However, portions of this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Credit may be taken for unplanned events that satisfy this SR.Verify battery capacity is[80%]of the manufacturer's rating when subjected to a performance discharge test or a modified performance discharge test.3.8.6-4(XY\se..-I-1) months AND 12 months when battery shows degradation, or has reached[85]%of the expected life with capacity<100%of manufacturer's rating 24 months when battery has reached[85]%of the expected life with capacity100%of manufacturer's rating Rev.3.0, 03/31/04 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE Battery Parameters
 
====3.8.6 FREQUENCY====
SR 3.8.6.5 SR 3.8.6.6 CEOG STS Verify each battery connected cell voltage is[2.07]V.-------------------------------
NOT E------------------------------
This Surveillance shall not be performed in MODE 1, 2, 3, or 4.However, portions of this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.Credit may be taken for unplanned events that satisfy this SR.Verify battery capacity is[80%]of the manufacturer's rating when subjected to a performance discharge test or a modified performance discharge test.3.8.6-4(XY\se..-I-1) months AND 12 months when battery shows degradation, or has reached[85]%of the expected life with capacity<100%of manufacturer's rating 24 months when battery has reached[85]%oftheexpected life with capacity100%of manufacturer's rating Rev.3.0, 03/31/04 Inverters - Operating
 
====3.8.7 SURVEILLANCE====
REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.7.1 alignment to required AC vital buses. CEOG STS Rev. 3.0. 03131104 SURVEILLANCE REQUIREMENTS SURVEILLANCE Inverters-Operating 3.8.7 FREQUENCY SR 3.8.7.1 Verify correct inverter voltage,[frequency,]
and alignment to required AC vital buses.CEOG STS 3.8.7-2 Rev.3.0, 03/31/04 Inverters - Shutdown 3.8.8 ACTIONS (continued)
CONDITION
/ REQUIRED ACTION A.2.2 Suspend movement of
[recently]
irradiated fuel assemblies.
A.2.3 Suspend operations involving positive reactivity additions that could result in loss of required SDM or boron concentration.
A.2.4 Initiate action to restore required inverters to OPERABLE status.
COMPLETION TIME lmmediately lmmediately lmmediately SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.8.1 Verify correct inverter voltage, [frequency,]
and alignments to required AC vital buses.
CEOG STS Rev. 3.0, 03/31/04 Inverters-Shutdown 3.8.8 ACTIONS (continued)
CONDITION REQUIRED ACTION A.2.2 Suspend movement of[recently]
irradiated fuel assemblies.
COMPLETION TIME Immediately A.2.3 Suspend operations Immediately involving positive reactivity additions that could result in loss of required SDM or boron concentration.
A.2.4 Initiate action to restore required inverters to OPERABLE status.SURVEILLANCE REQUIREMENTS SURVEILLANCE Immediately FREQUENCY SR 3.8.8.1 Verify correct inverter voltage,[frequency,]
and alignments to required AC vital buses.IT: days CEOG STS 3.8.8-2 Rev.3.0, 03/31104 Distribution Systems - Operating
 
====3.8.9 ACTIONS====
(continued)
CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and associated Completion Time not met.
E. Two or more electrical power distribution subsystems inoperable that result in a loss of safety function.
D.l Be in MODE 3. 6 hours AND D.2 Be in MODE 5. 36 hours I Enter LC0 3.0.3. Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.8.9.1 Verify correct breaker alignments and voltage to [required]
AC, DC, and AC vital bus electrical power distribution subsystems.
CEOG STS FREQUENCY Rev. 3.1, 12/01/05 Distribution Systems-Operating 3.8.9 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME D.Required Action and D.1 Be in MODE 3.6 hours associated Completion Time not met.AND D.2 Be in MODE 5.36 hours E.Two or more electrical E.1 Enter LCO 3.0.3.Immediately power distribution sUbsystems inoperable that result in a loss of safety function.SURVEILLANCE REQUIREMENTS SR 3.8.9.1 CEOG STS SURVEILLANCE Verify correct breaker alignments and voltage to[required]
AC, DC, and AC vital bus electrical power distribution subsystems.
3.8.9-2 FREQUENCY[days Q:
Rev.3.1,12/01/05 Distribution Systems - Shutdown 3.8.1 0 ACTIONS (continued)
CONDITION REQUIRED ACTION A.2.4 Initiate actions to restore required AC, DC, and AC vital bus electrical power distribution subsystems to OPERABLE status.
A.2.5 Declare associated required shutdown cooling subsystem(s) inoperable and not in operation.
COMPLETION TIME Immediately Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE I FREQUENCY SR 3.8.10.1 Verify correct breaker alignments and voltage to Edays t required AC, DC, and AC vital bus electrical power distribution subsystems.
..-. CEOG STS Rev. 3.0, 03/31/04 Distribution Systems-Shutdown 3.8.10 ACTIONS (continued)
CONDITION REQUIRED ACTION A.2.4 Initiate actions to restore required AC, DC, and AC vital bus electrical power distribution subsystems to OPERABLE status.A.2.5 Declare associated required shutdown cooling subsystem(s) inoperable and not in operation.
SURVEILLANCE REQUIREMENTS SURVEILLANCE COMPLETION TIME Immediately Immediately FREQUENCY SR 3.8.10.1 CEOG STS Verify correct breaker alignments and voltage to required AC, DC, and AC vital bus electrical power distribution subsystems.
3.8.10-2 Rev.3.0, 03/31/04 Boron Concentration 3.9.1 3.9 REFUELING OPERATIONS
 
====3.9.1 Boron====
Concentration LC0 3.9.1 Boron concentrations of the Reactor Coolant System, [the refueling canal, and the refueling cavity] shall be maintained within the limit specified in the COLR. APPLICABILITY: MODE
: 6. ---&--*--------------------------------------
NOTE ..........................................
-- Only applicable to the refueling canal and refueling cavity when connected to the RCS.
ACTIONS CONDITION A. Boron concentration not within limit. REQUIRED ACTION A.l Suspend CORE ALTERATIONS.
A.2 Suspend positive reactivity additions.
A.3 Initiate action to restore boron concentration to within limit.
COMPLETION TIME Immediately lmmediately Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.9.1.1 Verify boron concentration is within the limit specified in the COLR. FREQUENCY CEOG STS 3.9.1-1 Rev. 3.0, 03/31/04 Boron Concentration 3.9.1 3.9 REFUELING OPERATIONS
 
====3.9.1 Boron====
Concentration LCO 3.9.1 Boron concentrations of the Reactor Coolant System,[the refueling canal, and the refueling cavity]shall be maintained within the limit specified in the COLR.APPLICABILITY:
ACTIONS MODE 6.---------------------------------------------
NOTE-------------------------------------------.
Only applicable to the refueling canal and refueling cavity when connected to the RCS.CONDITION A.Boron concentration not A.1 within limit.AND A.2 AND A.3 SURVEILLANCE REQUIREMENTS REQUIRED ACTION Suspend CORE AL TERATIONS.
Suspend positive reactivity additions.
Initiate action to restore boron concentration to within limit.COMPLETION TIME Immediately Immediately Immediately SR 3.9.1.1 CEOG STS SURVEILLANCE Verify boron concentration is within the limit specified in the COLR.3.9.1-1 FREQUENCY Rev.3.0, 03/31/04 Nuclear lnstrumentation 3.9.2 3.9 REFUELING OPERATIONS
 
====3.9.2 Nuclear====
Instrumentation LC0 3.9.2 Two source range monitors (SRMs) shall be OPERABLE.
APPLICABILITY:
MODE 6. ACTIONS CONDITION A. One [required] SRM inoperable.
B. Two [required]
SRMs inoperable.
REQUIRED ACTION A.1 Suspend CORE ALTERATIONS.
A.2 Suspend operations that would cause introduction of coolant into the RCS with boron concentration less than required to meet the boron concentration of LC0 3.9.1. B.l Initiate action to restore one SRM to OPERABLE status.
 
===8.2 Perform===
SR 3.9.1 .I COMPLETION TIME Immediately Immediately Immediately Once per 12 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.2.1 Perform CHANNEL CHECK. I@ hours t, CEOG STS Rev. 3.0, 03/31/04 Nuclear Instrumentation 3.9.2 3.9 REFUELING OPERATIONS
 
====3.9.2 Nuclear====
Instrumentation LCO 3.9.2 Two source range monitors (SRMs)shall be OPERABLE.APPLICABILITY:
ACTIONS MODE 6.CONDITION REQUIRED ACTION COMPLETION TIME A.One[required]
SRM A.1 Suspend CORE Immediately inoperable.
AL TERATIONS.
AND A.2 Suspend operations that Immediately would cause introduction of coolant into the RCS with boron concentration less than required to meet the boron concentration of LCO 3.9.1.B.Two[required}
SRMs 8.1 Initiate action to restore one Immediately inoperable.
SRM to OPERABLE status.AND B.2 Perform SR 3.9.1.1.Once per 12 hours SURVEILLANCE REQUIREMENTS
-------------
.."_..,,,,,..,,,,.,,,,.,,....-SR 3.9.2.1 CEOG STS SURVEILLANCE Perform CHANNEL C14ECK.3.9.2-1 FREQUENCY@hours Rev.3.0.03/31/04 SURVEILLANCE REQUIREMENTS (continued)
SURVEILLANCE Nuclear Instrumentation 3.9.2 SR 3.9.2.2 ...............................
NOTE .............................. Neutron detectors are excluded from CHANNEL CALIBRATION.
Perform CHANNEL CALIBRATION.
CEOG STS FREQUENCY k8] months +\ Rev. 3.0. 03131104 SURVEILLANCE Nuclear Instrumentation
 
====3.9.2 FREQUENCY====
SR 3.9.2.2-------------------------------NOTE------------------------------
Neutron detectors are excluded from CHANNEL CALIBRATION.
CEOG STS Perform CHANNEL CALIBRATION.
3.9.2-2 Rev.3.0, 03/31/04 Containment Penetrations
 
====3.9.3 SURVEILLANCE====
REQUIREMENTS - SURVEILLANCE SR 3.9.3.1 Verify each required containment penetration is in the required status.
SR 3.9.3.2 ...............................
NOTE ............................. Not'required to be met for containment purge and exhaust valve(s) in penetrations closed to comply with LC0 3.9.3.c.l.
----------------+-----------------------------*----------------------
Verify each required containment purge and exhaust valve actuates to the isolation position on an actual or simulated actuation signal.
FREQUENCY CEOG STS Rev. 3.0, 03/31/04 Containment Penetrations
 
====3.9.3 SURVEILLANCE====
REQUIREMENTS SR 3.9.3.1 SR 3.9.3.2 CEOG STS SURVEILLANCE Verify each required containment penetration is in the required status.
NOTE Not'required to be met for containment purge and exhaust valve(s)in penetrations closed to comply with LCO 3.9.3.c.1.
Verify each required containment purge and exhaust valve actuates to the isolation position on an actual or simulated actuation signal.3.9.3-2 FREQUENCY Rev.3.0, 03/31/04 ACTIONS (continued)
CONDITION SDC and Coolant Circulation - High Water Level
 
====3.9.4 REQUIRED====
ACTION A.4 A.5 AND - A.6.q Close equipment hatch and secure with [four] bolts. Close one door in each air lock. Close each penetration providing direct access from the containment atmosphere to the outside atmosphere with a manual or automatic isolation valve, blind flange, or equivalent.
A.6.2 Verify each penetration is capable of being closed by an OPERABLE Containment Purge and Exhaust Isolation System.
COMPLETION TIME 4 hours 4 hours ' 4 hours 4 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.4.1 reactor coolant at a flow rate of r [2200] gpm. CEOG STS Rev. 3.0, 03/31/04 ACTIONS (continued)
CONDITION SOC and Coolant Circulation
-High Water Level 3.9.4 REQUIRED ACTION COMPLETION TIME A.4 Close equipment hatch and 4 hours secure with[four]bolts.AND A.5 Close one door in each air lock.4 hours A.6.1 Close each penetration 4 hours providing direct access from the containment atmosphere to the outside atmosphere with a manual or automatic isolation valve, blind flange, or equivalent.
A.6.2 Verify each penetration is capable of being closed by an OPERABLE Containment Purge and Exhaust Isolation System.SURVEILLANCE REQUIREMENTS SURVEILLANCE 4 hours FREQUENCY SR 3.9.4.1 CEOG STS Verify one SOC loop is in operation and circulating reactor coolant at a flow rate of[2200]gpm.3.9.4-2[i2 hours Jf:--_
Rev.3.0, 03/31/04 SDC and Coolant Circulation - Low Water Level
 
====3.9.5 SURVEILLANCE====
 
REQUIREMENTS SURVEILLANCE Verify required SDC loops are OPERABLE and one SDC loop is in operation.
SR 3.9.5.2 Verify correct breaker alignment and indicated power available to the required SDC pump that is not in operation.
CEOG STS FREQUENCY Rev. 3.0, 03/31/04 soc and Coolant Circulation
-Low Water Level 3.9.5 SURVEILLANCE REQUIREMENTS SR 3.9.5.1 SR 3.9.5.2 CEOG STS SURVEILLANCE Verify required SDC loops are OPERABLE and one SOC loop is in operation.
Verify correct breaker alignment and indicated power available to the required SOC pump that is not in operation.
3.9.5-3 FREQUENCY IT.?hours (InSe.rt-l-Rev.3.0, 03/31/04 Refueling Water Level 3.9.6 3.9 REFUELING OPERATIONS
 
====3.9.6 Refueling====
Water Level LC0 3.9.6 Refueling water level shall be maintained 2 23 ft above the top of reactor vessel flange. APPLICABILITY: During movement of [recently] irradiated fuel assemblies within containment.
ACTIONS CONDITION I REQUIRED ACTION I COMPLETION TIME SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY A. Refueling water level not within limit.
SR 3.9.6.1 Verify refueling water level is t 23 ft above the top of k4 hours reactor vessel flange. CEOG STS A.l Suspend movement of [recently] irradiated fuel assemblies within containment.
Rev. 3.0, 03/31/04 Immediately Refueling Water Level 3.9.6 3.9 REFUELING OPERATIONS
 
====3.9.6 Refueling====
Water Level LCO 3.9.6 Refueling water level shall be maintained 2:: 23 ft above the top of reactor vessel flange.APPLICABILITY:
ACTIONS During movement of[recently]
irradiated fuel assemblies within containment.
CONDITION A.Refueling water level not A.1 within limit.SURVEILLANCE REQUIREMENTS REQUIRED ACTION Suspend movement of[recently]
irradiated fuel assemblies within containment.
COMPLETION TIME Immediately SURVEILLANCE FREQUENCY SR 3.9.6.1 Verify refueling water level is 2:: 23 ft abovethetop of@hoursreactor vessel flange.ce;;;;;rW CEOG STS 3.9.6-1 Rev.3.0, 03/31/04 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.1 7 Batten/ Monitorinq and Maintenance Program This Program provides for battery restoration and maintenance, based on [the recommendations of IEEE Standard 450-1995, "IEEE Recommended Practice for Maintenance, Testing, and Replacement of Vented Lead-Acid Batteries for Stationary Applications," or of the battery manufacturer] including the following a. Actions to restore battery cells with float voltage
< [2.13] V, and b. Actions to equalize and test battery cells that had been discovered with electrolyte level below the minimum established design limit. CEOG STS Rev. 3.1, 12/01/05 Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.17 Battery Monitoring and Maintenance Program This Program provides for battery restoration and maintenance, based on[the recommendations of IEEE Standard 450-1995,"IEEE Recommended Practice for Maintenance, Testing, and Replacement of Vented Lead-Acid Batteries for Stationary Applications," or of the battery manufacturer}
including the following a.b.Actions to restore battery cells with float voltage<[2.13]V, and Actions to equalize and test battery cells that had been discovered with electrolyte level below the minimum established design limit.CEOGSTS 5.5-18 Rev.3.1,12/01/05 SDM (Analog)
B 3.1 .I BASES SURVEILLANCE SR 3.1 .I .I REQUIREMENTS SDM is verified by performing a reactivity balance calculation, considering the listed reactivity effects: a. RCS boron concentration, b. CEA positions, c. RCS average temperature, d. Fuel burnup based on gross thermal energy generation, e. Xenon concentration, f. Samarium concentration, and
: g. Isothermal temperature coefficient (ITC). Using the ITC accounts for Doppler reactivity in this calculation because the reactor is subcritical and the fuel temperature will be changing at the same rate as the RCS. bhe Frequency of 24 hours is based on the generally slow change in required boron concentration, and also allows sufficient time for the operator to collect the required data, which includes performing a boron concentration analysis, and complete the calculation.
*--, - REFERENCES
: 1. 10 CFR 50, Appendix A, GDC 26. (ITS ~e I-"+ Z> 2. FSAR, Section
[ 1. 3. FSAR, Section [ 1. CEOG STS Rev. 3.0, 03131104 SDM (Analog)B 3.1.1 BASES SURVEILLANCE REQUIREMENTS SR 3.1.1.1 SDM is verified by performing a reactivity balance calculation, considering the listed reactivity effects: a.RCS boron concentration, b.CEA positions, c.ReS average temperature, d.Fuel burnup based on gross thermal energy generation, e.Xenon concentration, f.Samarium concentration, and g.Isothermal temperature coefficient (ITC).Using the ITC accounts for Doppler reactivity in this calculation because the reactor is subcritical and the fuel temperature will be changing at the same rate as the RCS.1'0 CFR 50, Appendix A, GDG 26.1.(lhe Frequency of 24 hours is based on the generally slow change in requiredboronconcentration, and also allows sufficient time for the operator to collect the required data, which includes performing a boron concentration analysis, and complete the calculation.
f-._.REFERENCES 2.FSAR, Section[].3.FSAR, Section[].4.10 CFR 100.CEOG STS B 3.1.1-5 Rev.3.0, 03/31/04 BASES Reactivity Balance (Analog)
B 3.1.2 SURVEILLANCE SR 3.1.2.1 REQUIREMENTS Core reactivity is verified by periodic comparisons of measured and predicted RCS boron concentrations. The comparison is made considering that other core conditions are fixed or stable including CEA position, moderator temperature, fuel temperature, fuel depletion, xenon concentration, and samarium concentration.
The Surveillance is performed prior to entering MODE 1 as an initial check on core conditions and design calculations at BOC. The SR is modified by three Notes.
Note 1 in the Surveillance column indicates that the normalization of predicted core reactivity to the measured value must take place within the first 60 effective full power days (EFPD) after each fuel loading. This allows sufficient time for core conditions to reach steady state, but prevents operation for a large fraction of the fuel cycle ithout establishing a benchmark for the design calculations.
&e required subsequent Frequency of 31 EFPD following the initial 60 EFPD after entering MODE I, is acceptable, based on the slow rate of core changes due to fuel depletion and the presence o etc.) for prompt indication of an anomaly after 60 EFPD," is added to the Frequenc not required prior to entering MO MODE 2 entry to verify core reac REFERENCES 1.
10 CFR 50, Appendix A, GDC 26, GDC 28, and GDC 29. 2. FSAR, Section [ 1. CEOG STS Rev. 3.0, 03/31/04 BASES SU RVEI LLANCE REQUIREMENTS Reactivity Balance (Analog)B 3.1.2 SR 3.1.
 
==2.1 REFERENCES==
 
Core reactivity is verified by periodic comparisons of measured and predicted ReS boron concentrations.
The comparison is made considering that other core conditions are fixed or stable including CEA position, moderator temperature, fuel temperature, fuel depletion, xenon concentration, and samarium concentration.
The Surveillance is performed prior to entering MODE 1 as an initial check on core conditions and design calculations at BOC.The SR is modified by three Notes.Note 1 in the Surveillance column indicates that the normalization of predicted core reactivity to the measured value must take place within the first 60 effective full power days (EFPD)after each fuel loading.This allows sufficient time for core conditions to reach steady state, but prevents operation for a large fraction of the fuel establishing a benchmark for the design calculations.l.Ih,e required subsequent Frequency of 31 EFPD following the initial 60 EFPD after entering MODE 1, is acceptable, based on the slow rate of core changes due to fuel depletion and the presence of ot r indicators e.., QPTR, etc.)for prompt indication of an anomaly.A second Note,"only required after 60 EFPD," is added to the Frequency column to allow this.Note 2 in the Surveillance column indicates that the performance of SR 3.1.2.1 is not required prior to entering MODE 2.This Note is required to allow a MODE 2 entry to verify core reactivity, because LCO Applicability is for MODES 1 and 2.rfr,;;;--"'\-------"" 1.10 CFR 50, Appendix A, GOC 26, GOC 28, and GDC 29.2.FSAR, Section[].CEOG STS B 3.1.2-5 Rev.3.0, 03/31/04 CEA Alignment (Analog)
B 3.1.4 BASES ACTIONS (continued)
When the CEA deviation circuit is inoperable, performing SR 3.1.4.1, within 1 hour and every 4 hours thereafter, ensures improper CEA alignments are identified before unacceptable flux distributions occur.
The specified Completion Times take into account other information continuously available to the'operator in the control room, so that during CEA movement, deviations can be detected, and the protection provided by the CEA inhibit and deviation circuit is not required. If the Required Action or associated Completion Time of Condition A, Condition B, or Condition C is not met, one or more regulating or shutdown CEAs are inoperable, or two or more CEAs are misaligned by > [15 inches], the unit is required to be brought to MODE
: 3. By being brought to MODE 3, the unit is brought outside its MODE of applicability. Continued operation is not allowed in the case of more than one CEA misaligned from any other CEA in its group by > [I5 inches], or one or more CEAs inoperable. This is because these cases are indicative of a loss of SDM and power distribution, and a loss of safety function, respectively. When a Required Action cannot be completed within the required Completion Time, a controlled shutdown should be commenced. The allowed Completion Time of 6 hours is reasonable, based on operating experience, for reaching MODE 3 from full power conditions in an orderly manner and without challenging plant systems.
SURVEILLANCE SR 3.1.4.1 fi->a REQUIREMENTS verification@
individual CEA positions are within
[7 inches] (indicated reed switch positions) of all other CEAs in the group within 1 hour of any CEA movement of
> 7.5 inches The CEA position verification after each movement of > 7.5 inches ensures that the CEAs in that group are properly aligne at the time when CEA misalignments are most likely to have occurred.
f The 12 hour Frequency allows the operator to detect a CEA that is beginning to deviate from its expected position.
The specified Frequency takes into account other CEA position information that is continuously available to the operator in the control room, so that during CEA movement, deviations can be detected, and protection can be provided by the CEA motion inhibit and deviation circuits.
e-q CEOG STS B 3.1.4-7 Rev. 3.0. 03/31/04 BASES ACTIONS (continued)
CEA Alignment (Analog)B 3.1.4-.SURVEILLANCE REQUIREMENTS When the CEA deviation circuit is inoperable, performing SR 3.1.4.1, within 1 hour and every 4 hours thereafter, ensures improper CEA alignments are identified before unacceptable flux distributions occur.The specified Completion Times take into account other information continuously available to the'operator in the control room, so that during CEA movement, deviations can be detected, and the protection provided by the CEA inhibit and deviation circuit is not required.If the Required Action or associated Completion Time of Condition A, Condition B, or Condition C is not met, one or more regulating or shutdown CEAs are inoperable, or two or more CEAs are misaligned by>[15 inches], the unit is required to be brought to MODE 3.By being brought to MODE 3, the unit is brought outside its MODE of applicability.
Continued operation is not allowed in the case of more than one CEA misaligned from any other CEA in its group by>[15 inches], or one or more CEAs inoperable.
This is because these cases are indicative of a loss of SDM and power distribution, and a loss of safety function, respectively.
When a Required Action cannot be completed within the required Completion Time, a controlled shutdown should be commenced.
The allowed Completion Time of 6 hours is reasonable, based on operating experience, for reaching MODE 3 from full power conditions in an orderly manner and without challenging plant systems.SR 3.1.4.1 individual CEA positions are within[7 inches](indicated reed switch positions) of all other CEAs in the group within 1 hour of any CEA movement of>7.5 inches
_
The CEA position verification after each movement of>7.5 inches ensures that the CEAs in that group are properly align..&sect;9 at the time when CEA misalignments are most likely to have occurred.LIhe 12 hour Frequency allows the operator to detect a CEA that is beginning to deviate from its expected position.The specified Frequency takes into account other CEA position information that is continuously available to the operator in the control room, so that during CEA movement, deviations can be detected, and protection can be provided by the CEA motion inhibit and deviation circuits.
..', n...)erl CEOG STS Rev.3.0, 03/31/04 CEA Alignment (Analog)
B 3.1.4 BASES SURVEILLANCE REQUIREMENTS (continued) Demonstrating the CEA motion inhibit OPERABLE verifies that the CEA motion inhibit is functional, even if it is not regularly operated.
Ehe 92 day Frequency takes into account other information continuously available to the operator in the control room, so that during CEA movement, deviations can be detected, and wotection can be ~rovided bv the CEA +-*-..**.-* deviation circuits. Demonstratin the CEA deviation circuit is OPERABLE verifies the circuit is functional.
I? The 92 day Frequency takes into account other information continuously available to the operator in the control room, so that during CEA movement, deviations can be detected, and protection can be provided by the CEA motion inhibit. e"- Verifying each CEA is trippable would require that each CEA be tripped. In MODES 1 and 2, tripping each CEA would result in radial or axial scillations. Therefore, individual CEAs are exercised o provide increased confidence that all CEAs continue to en if they are not regularly tripped.
A movement of [5 ~nches] is adequate to demonstrate motion without exceeding the alignment limit when only one CEA is being moved. rhe 92 day Frequency takes into consideration other information available to the operator in the control room and other surveillances being performed more frequently, which add to the determination of OPERABILITY of the determination of the trippability (0 made, and appropriate action taken. CEOG STS Rev. 3.0, 03/31/04 CEA Alignment (Analog)B 3.1.4 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.1.4.2 Demonstrating the CEA motion inhibit OPERABLE verifies that the CEA motion inhibit is functional, even if it is not regularly operated.\:f!1e 92 day Frequency takes into account other information continuously available to the operator in the control room, so that during CEA movement, deviations can be detected, and protection can be provided by the CEA deviation circuits.
SR 3.1.4.3 CEA deviation circuit is OPERABLE verifies the circuit is functional.
[Ihe 92 day Frequency takes into account other information continuously available to the operator in the control room, so that during CEA movement, deviations can be detected, and protection can be provided by the CEA motion inhibit.
SR 3.1.4.4 Verifying each CEA is trippable would require that each CEA be tripped.In MODES 1 and 2, tripping each CEA would result in radial or axial Qower tilts c Therefore, individual CEAs are exercised provide increased confidence that all CEAs continue to.be4rfp'pabTe, even if they are not regularly tripped.A movement of[5 inches)is adequate to demonstrate motion without exceeding the alignment limit when only one CEA is being moved.[fhe 92 day Frequency takes into consideration other information available to the operator in the control room and other surveillances being performed more frequently, which add to the determination of OPERABILITY of the CEAs.Between required performances of SR 3.1.4.4, if a CEA(s)is discovered to be immovable, but remains trippable, the CEA is considered to be OPERABLE.At any time, if a CEA(s)is immovable, a determination of the trippability (OPERABILITY) of the CEA(s)must be
__CEOG STS B 3.1.4-8 Rev.3.0, 03/31/04 CEA Alignment (Analog)
B 3.1.4 BASES SURVEILLANCE REQUIREMENTS (continued)
Performance of a CHANNEL FUNCTIONAL TEST of each reed switch position transmitter channel ensures the channel is OPERABLE and capable of indicating CEA position over the entire length of the CEA's travel. A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specificatio s tests at least once per refueling interval with applicable extensions.&nce this Surveillance must be performed when the reactor is shut down, an 18 month Frequency to be coincident with refueling outage was selected. Operating experience has shown that these components usually pass this Surveillance when performed at a Frequency of once every 18 months. Furthermore, the Frequency takes into account other surveillances being performed at shorter Frequencies, which determine the OPERABILITY of the CEA Reed switch Indication System.
d+w* Verification of CEA drop times determined that the maximum CEA drop time permitted is consistent with the assumed drop time used in that safety analysis (Ref.
7). Measuring drop times prior to reactor criticality, after reactor vessel head removal, ensures that reactor internals and CEDM will not interfere with CEA motion or drop time and that no degradation in these systems has occurred that would adversely affect CEA motion or drop time. Individual CEAs whose drop times are greater than safety analysis assumptions are not OPERABLE.
This SR is performed prior to criticality, based on the need to perform this Surveillance under the conditions that apply during a unit outage and because of the potential for an unplanned unit transient if the Surveillance were performed with the reactor at power. CEOG STS B 3.1.4-9 Rev. 3.0, 03/31/04 CEA Alignment (Analog)B 3.1.4 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.1.4.5 Performance of a CHANNEL FUNCTIONAL TEST of each reed switch position transmitter channel ensures the channel is OPERABLE and capable of indicating CEA position over the entire length of the CEA's travel.A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical tests at least once per refueling interval with applicable extensions.l&sect;ince this Surveillance must be performed when the reactor is shut down, an 18 month Frequency to be coincident with refueling outage was selected.Operating experience has shown that these components usually pass this Surveillance when performed at a Frequency of once every 18 months.Furt,hermore, the Frequency takes into account other surveillances being performed at shorter Frequencies, which determine the OPERABILITY of the CEA Reed Switch Indication System.
SR 3.1.4.6 Verification of CEA drop times determined that the maximum CEA drop time permitted is consistent with the assumed drop time used in that safety analysis (Ref.7).Measuring drop times prior to reactor criticality, after reactor vessel head removal, ensures that reactor internals and CEDM will not interfere with CEA motion or drop time and that no degradation in these systems has occurred that would adversely affect CEA motion or drop time.Individual CEAs whose drop times are greater than safety analysis assumptions are not OPERABLE.This SR is performed prior to criticality, based on the need to perform this Surveillance under the conditions that apply during a unit outage and because of the potential for an unplanned unit transient if the Surveillance wereperformedwith the reactor at power.CEOG STS B 3.1.4-9 Rev.3.0, 03/31/04 Shutdown CEA Insertion Limits (Analog)
B 3.1.5 BASES SURVEILLANCE REQUIREMENTS (continued)
Ence the shutdown CEAs are positioned manually by the control room operator, verification of shutdown CEA position at a Frequency of 12 hours is adequate to ensure that the shutdown CEAs are within their insertion limits. Also, the 12 hour Frequency takes into account other information available to the operator in the control room for the purpose of monitoring the status of the shutdown CEAs. 4- - *, 2. 10 CFR 50.46 3. FSAR, Section I 1. CEOG STS Rev. 3.0, 03/31/04 Shutdown CEA Insertion Limits (Analog)B 3.1.5 BASES 1.10 CFR 50, Appendix A, GDC 10 and GDC 26.
SURVEILLANCE REQUIREMENTS (continued)
[&sect;.ince the shutdown CEAs are positioned manually by the control room operator, verification of shutdown CEA position at a Frequency of 12 hours is adequate to ensure that the shutdown CEAs are within their insertion limits.Also, the 12 hour Frequency takes into account other information available to the operator in the control room for the purpose of monitoring the status of the shutdown CEAs.-t:..,..,,,,, REFERENCES 2.10 CFR 50.46.3.FSAR, Section[].CEOG STS B 3.1.5-4 Rev.3.0, 03/31/04 Regulating CEA Insertion Limits (Analog)
B 3.1.6 BASES ACTIONS (continued) When a Required Action cannot be completed within the required Completion Time, a controlled shutdown should be commenced.
The allowed Completion Time of 6 hours is reasonable, based on operating experience, for reaching MODE 3 from full power conditions in an orderly manner and without challenging plant systems.
SURVEILLANCE SR 3.1.6.1 REQUIREMENTS E, verification of each regulating s sufficient to detect CEA positions its, and to provide the operator with time to undertake the Required Action(s) should the sequence or insertion limits be found to be exceeded.Ehe 12 hour Frequency also takes into account the indicatio y the PDlL alarm circuit and other information about CE ble to the operator in the SR 3.1.6.1 is modified by a Note indicating that entry is allowed into MODE 2 for 12 hours without having performed the SR. This is necessary, since the unit must be in the applicable MODES in order to perform Surveillances that demonstrate the LC0 limits are met. Verification of the accumulated time of CEA group insertion between the long term steady state insertion limits and the transient insertion limits ensures the cumulative time limits are not Freauencv ensures the o~erator identifies app&ched before it is riached. ., Demonstrating the PDlL alarm circuit OPERABLE verifies that the PDlL alarm circuit is functional.
ae 31 day Frequency takes into account other Surveillances being perfor s that identify improper CEA alignments.
CEOG STS B 3.1.6-7 Rev. 3.0, 03/31/04 Regulating CEA Insertion Limits (Analog)B 3.1.6 BASES ACTIONS (continued)
When a Required Action cannot be completed within the required Completion Time, acontrolledshutdown should be commenced.
The allowed Completion Time of 6 hours is reasonable, based on operating experience, for reaching MODE 3 from full power conditions in an orderly manner and without challenging plant systems.SURVEILLANCE REQUIREMENTS SR 3.1.6.1 With the POlL alarm cir ABLE, verification of each regulating CEA group positior(everl)l1 ours s sufficient to detect CEA positions that may approach tn'Ei-acceptal;Te'j'imits, and to provide the operator with time to undertake the Required Action(s)should the sequence or insertion limits be found to be exceeded.Uhe 12 hour Frequency alsotakesinto account the indication provided by the POlL alarm circuit and other information abo.ut CE...A..
to the operator in the control room.J."""".", t\Ii!")-",.;, 1""':1';:,
l t"1 flit, SR 3.1.6.1 is modified by a Note indicating that entry is allowed into MODE 2 for 12 hours without having performed the SR.This is necessary, since the unit must be in the applicable MODES in order to perform Surveillances that demonstrate the LCO limits are met.SR 3.1.6.2 Verification of the accumulated time of CEA group insertion between the long term steady state insertion limits and the transient insertion limits ensures the cumulative time limits are not exceeded.fThe 24 hour Frequency ensures the operator identifies a time limit'tflat is being approached before it is reached.
SR 3.1.6.3 Demonstrating the PDIL alarm circuit OPERABLE verifies that the POlL alarm circuit is functional.(Ihe 31 day Frequencytakesinto account other Surveillances being performed at that identify improper CEA alignments. t 2...::)CEOG STS B 3.1.6-7 Rev.3.0, 03/31/04 STE - SDM (Analog)
B 3.1.7 BASES LC0 This LC0 provides that a minimum amount of CEA worth is immediately available for reactivity control when CEA worth measurement tests are performed. The STE is required to permit the periodic verification of the actual versus predicted worth of the regulating and shutdown CEAs. The SDM requirements of LC0 3.1.1, the shutdown CEA insertion limits of LC0 3.1.5, and the regulating CEA insertion limits of LC0 3.1.6 may be suspended.
APPLICABILITY This LC0 is applicable in MODES 2 and 3. Although CEA worth testing is conducted in MODE 2, sufficient negative reactivity is inserted during the performance of these tests to result in temporary entry into MODE 3. Because the intent is to immediately return to MODE 2 to continue CEA worth measurements, the STE allows limited operation to 6 consecutive hours in MODE 3, as indicated by the Note, without having to borate to meet the SDM requirements of LC0 3.1 .I. ACTIONS With any CEA not fully inserted and less than the minimum required reactivity equivalent available for insertion, or with all CEAs inserted and the reactor subcritical by less than the reactivity equivalent of the highest worth CEA, restoration of the minimum SDM requirements must be accomplished by increasing the RCS boron concentration.
The required Completion Time of 15 minutes for initiating boration allows the operator sufficient time to align the valves and start the boric acid pumps and is consistent with the Completion Time of LC0 3.1 -1. SURVEILLANCE SR 3.1.7.1 REQUIREMENTS Verification of the position of each partially or fully withdrawn full length or part length CEA is necessary to ensure that the minimum ne ative reactivity requirements for insertion on a trip are preserved. A 2 hour within the acceptance criteria.
eh, f Frequency is sufficient for the operator to verify that each CEA position is Prior demonstration that each CEA to be withdrawn from the core during PHYSICS TESTS is capable of full insertion, when tripped from at least a 50% withdrawn position, ensures that the CEA will insert on a trip signal.
The Frequency ensures that the CEAs are OPERABLE prior to reducing SDM to less than the limits of LC0 3.1 .I. CEOG STS B 3.1.7-4 Rev. 3.0, 03/31/04 BASES LCO APPLICABI L1TY ACTIONS SURVEILLANCE REQUIREMENTS STE-SDM (Analog)B 3.1.7 This LCO provides that a minimum amount of CEA worth is immediately available for reactivity control when CEA worth measurement tests are performed.
The STE is required to permit the periodic verification of the actual versus predicted worth of the regulating and shutdown CEAs.The SDM requirements of LCO 3.1.1, the shutdown CEA insertion limits of LCO 3.1.5, and the regulating CEA insertion limits of LCO 3.1.6 may be suspended.
This LCO is applicable in MODES 2 and 3.Although CEA worth testing is conducted in MODE 2, sufficient negative reactivity is inserted during the performance of these tests to result in temporary entry into MODE 3.Because the intent is to immediately return to MODE 2 to continue CEA worth measurements, the STE allows limited operation to 6 consecutive hours in MODE 3, as indicated by the Note, without haVing to borate to meet the SDM requirements of LCO 3.1.1.With any CEA not fully inserted and less than the minimum required reactivity equivalent available for insertion, or with all CEAs inserted and the reactor subcritical by less than the reactiVity equivalent of the highest worth CEA, restoration of the minimum SDM requirements must be accomplished by increasing theRCSboron concentration.
The required Completion Time of 15 minutes for initiating boration allows the operator sufficient time to align the valves and start the boric acid pumps and is consistent with the Completion Time of LCO 3.1.1.SR 3.1.7.1 Verification of the position of each partially or fully withdrawn full length or part length CEA is necessary to ensure that the minimum reactivity requirements for insertion on a trip are preserved.tf.
2 hour Frequency is sufficient for the operator to verify that each CEA position is within the acceptance criteria.
:r.(*'I.3er'SR 3.1.7.2 Prior demonstration that each CEA to be withdrawn from the core during PHYSICS TESTS is capable of full insertion, when tripped from at least a 50%withdrawn position, ensures that the CEA will insert on a trip signal.The Frequency ensures that the CEAs areOPERABLEprior to reducing SDM to less than the limits of LCO 3.1.1.CEOG STS B 3.1.7-4 Rev.3.0, 03/31/04 STE - MODES 1 and 2 (Analog) B 3.1.8 BASES ACTIONS (continued)
Suspension of PHYSICS TESTS exceptions requires restoration of each of the applicable LCOs to within specification.
SURVEILLANCE SR 3.1.8.1 REQUIREMENTS Verifying that THERMAL POWER is equal to or less than that allowed by the test power plateau, as specified in the PHYSICS TEST procedure and required by the safety analysis, ensures that adequate LHR and DNB parameter margins are maintained while LCOs are suspended.
@he 1 hour Frequency is sufficient, based on the slow rate of power change and increased operational controls in place during PHYSICS TESTS:& REFERENCES I. 10 CFR 50, Appendix B, Section XI. (r& 2. 10 CFR 50.59. 3. Regulatory Guide 1.68, Revision 2, August 1978. 4. ANSIIANS-19.6.1-1985, December 13, 1985. 5. FSAR, Chapter
[14]. 6. FSAR, Section [15.3.2.1].
: 7. 10 CFR 50.46. CEOG STS Rev. 3.0, 03131104 STE-MODES 1 and 2 (Analog)B 3.1.8 BASES ACTIONS (continued)
Suspension of PHYSICS TESTS exceptions requires restoration of each of the applicable LCOs to within specification.
SURVEILLANCE SR 3.1.8.1 REQUIREMENTS REFERENCES Verifying that THERMAL POWER is equal to or less than that allowed by the test power plateau, as specified in the PHYSICS TEST procedure and required by the safety analysis, ensures that adequate LHR and DNB parameter margins are maintained while LCOs are suspended.
IThe 1 hour Frequency is sufficient, based on the slow rate of power change and increased operational controls in place during PHYSICS TESTS.1.10 CFR 50, Appendix B, Section XI.2.10 CFR 50.59.3.Regulatory Guide 1.68, Revision 2, August 1978.4.ANSI/ANS-19.6.1-1985, December 13,1985.5.FSAR, Chapter[14J.6.FSAR, Section[15.3.2.1 J.7.10 CFR 50.46.CEOG STS B 3.1.8-5 Rev.3.0, 03/31/04 SDM (Digital)
B 3.1.1 BASES SURVEILLANCE SR 3.1 .I .I REQUIREMENTS SDM is verified by performing a reactivity balance calculation, considering the listed reactivity effects: a. RCS boron concentration, b. CEA positions, c. RCS average temperature, d. Fuel burnup based on gross thermal energy generation, e. Xenon concentration, f. Samarium concentration.
and g. Isothermal temperature coefficient (ITC).
Using the ITC accounts for Doppler reactivity in this calculation because the reactor is subcritical, and the fuel temperature will be changing at the same rate as the RCS. Ehhe Frequency of 24 hours is based on the generally slow change in required boron concentration, and also allows sufficient time for the operator to collect the required data, which includes performing a boron concentration analysis, and complete the calculation.
~&-_mM--~
-- REFERENCES I. 10 CFR 50, Appendix A, GDC 26. (~nsert 2J 2. FSAR, Section
[15.4.2].
: 3. FSAR, Section [15.4.2].
: 4. 10 CFR 100. CEOG STS Rev. 3.0, 03/31/04 BASES SURVEILLANCE REQUIREMENTS SOM (Digital)B 3.1.1 SR 3.1.1.1 SDM is verified by performing a reactivity balance calculation, considering the listed reactivity effects: a.RCS boron concentration, b.CEA positions, c.RCS average temperature, d.Fuel burnup based on gross thermal energy generation, e.Xenon concentration, f.Samarium concentration, and g.Isothermal temperature coefficient (ITC).REFERENCES 1.10 CFR 50, Appendix A, GDC 26.CEOG STS 2.FSAR, Section[15.4.2].3.FSAR, Section[15.4.2].4.10 CFR 100.B 3.1.1-5 Rev.3.0, 03/31/04 Reactivity Balance (Digital)
B 3.1.2 BASES SURVEILLANCE SR 3.1.2.1 i REQUIREMENTS Core reactivity is verified by periodic comparisons of measured and predicted RCS boron concentrations. The comparison is made considering that other core conditions are fixed or stable including CEA position, moderator temperature, fuel temperature, fuel depletion, xenon concentration, and samarium concentration.
The Surveillance is performed prior to entering MODE 1 as an initial check on core conditions and design calculations at BOC.
The SR is modified by three Notes. The first Note indicates that the normalization of predicted core reactivity to the measured value must take place within the first 60 effective full power days (EFPD) after each fuel loading.
This allows sufficient time for core conditions to reach steady state, but prevents operation for a large fraction of the fuel cycle without establishing a benchmark for the design calculations.
Ehe required subsequent Frequency of 31 EFPD, following the initial 60 EFPD after entering MODE 1, is acceptable, based on the REFERENCES I. 10 CFR 50, Appendix A, GDC 26, GDC 28, and GDC 29. 2. FSAR. Section i 1. CEOG STS Rev. 3.0, 03/31/04 Reactivity Balance (Digital)B 3.1.2 BASES SURVEILLANCE REQUIREMENTS SR 3.1.2.1 Core reactivity is verified by periodic comparisons of measured and predicted RCS boron concentrations.
The comparison is made considering that other core conditions are fixed or stable including CEA position, moderator temperature, fuel temperature, fuel depletion, xenon concentration, and samarium concentration.
The Surveillance is performed prior to entering MODE 1 as an initial check on core conditions and design calculations at BOC.The SR is modified by three Notes.The first Note indicates that the normalization of predicted core reactivity to the measured value must take place within the first 60 effective full power days (EFPD)after each fuel loading.This allows sufficient time for core conditions to reach steady state, but prevents operation for a large fraction of the fuel cycle without establishing a benchmark for the design calculations.
{ff1e required subsequent Frequency of 31 EFPD, following the initial 60 EFPD after entering MODE 1, is acceptable, based on the slow rate of core changes due to fuel depletion and the presence of other indicators (e.g., QPTR)for prompt indication of an anomaly.Note,"only required after 60 EFPD," is added to the Frequency column to allow this.Another Note indicates that the performance of SR 3.1.2.1 is not required prior to entering MODE 2.This Note is required to allow a MODE 2 entry to verify core reactivity because Applicability is for MODES 1 and 2.n REFERENCES 1.10 CFR 50, Appendix A, GDC 26, GOC 28, and GOC 29.2.FSAR, Section[].CEOG STS B 3.1.2-5 Rev.3.0, 03/31/04 CEA Alignment (Digital)
B 3.1.4 BASES ACTIONS (continued) Continued operation is not allowed in the case of more than one CEA(s) misaligned from any other CEA in its group by
> [I9 inches], or with one or more full length CEAs inoperable SURVEILLANCE SR 3.7.4.1 REQUIREMENTS Verification that individual CEA positions are within [7 inches] (indicated reed switch positions) of all other CEAs in the group($-b llows the operator to detec is beginninq to&z hau) its expected position.
The equency takes into other CEA position information that is continuously available to the operator in the control room, so that during actual CEA motion, 4 99y Cdeviations can immediately be detected.
4, -.,a- 5,p3./.'11 SR 3.1.4.2 OPERABILITY of at least two CEA position indicator channels is required to determine CEA positions, and thereby ensure compliance with the CEA alignment and insertion limits.
The CEA full in and full out limits provide an additional independent means for determining the CEA positions when CEAs are at either their fully inserted or fully withdrawn positions. Verifying each full length CEA is trippable would require that each CEA be tripped. In MODES 1 and 2 tripping each full length CEA would result in radial or axial oower tilts. or oscillations. Therefore individual full lenath - - CEAs are exerciied~~-?Jto provide increased confidence that all full length CEAs continue to be trippable, even if they are not regularly tripped. A movement of
[5 inches] is adequate to demonstrate motion without exceediqg the alignment limit when only one full length CEA is being moved. Ehe 92 day Frequency takes into consideration other information available to the operator in the control room and other surveillances being performed more frequently, determination of OPERABILITY of the CEAs performances of SR 3.1.4.3, if a CEA(s) is discovered to be immovable, the CEA is considered to be OPERABLE. At anytime, if a CEA(s) is immovable, a determination of the trippability (OPERABILITY) of that CEA(s) must be made, and appropriate action taken. CEOG STS - Rev. 3.0, 03/31/04 CEA Alignment (Digital)B 3.1.4 BASES ACTIONS (continued)
Continued operation is not allowed in the case of more than one CEA(s)misaligned from any other CEA in its group by>[19 inches}, or with one or more full length CEAs inoperable SR 3.1.4.2 SR 3.1.4.1 Verification that individual CEA positions are within[7 inches}(indicated reed switch positions) of all other CEAs in the group(fit a..?.RouD the operator to detect a CEA th t is be innin to 1:<
::tefOm its expected position.The sled requency takes into account other CEA position information that is continuously available to the operator in the control room, so that during actual CEA motion, deviations can immediately be detected.<-"_'""_"-"-ij;
""..".'.t-\Se..t'"''C 2--OPERABILITY of at least two CEA position indicator channels is required to determine CEA positions, and thereby ensure compliance with the CEA alignment and insertionlimits.The CEA full in and full out limits provide an additional independent means for determining the CEA positions when the CEAs are at either their fully inserted or fully withdrawn positions.
"'-----fl/'.
SURVEILLANCE REQUIREMENTS SR 3.1.4.3 Verifying each full length CEA is trippable would require that each CEA be tripped.In MODES 1 and 2 tripping each full length CEA would result in radial or axial power tilts, or oscillations.
Therefore individual full length CEAs are exercised@vert 9:ydayS>to provide increased confidence that all full length CEAs continue to be trippable, even if they are not regularly tripped.A movement of[5 inches}is adequate to demonstrate motion without exceeding the alignment limit when only one full length CEA is being moved.(ihe 92 day Frequency takes into consideration other information available to the operator in the control room and other surveillances being performed more frequently, which determination of OPERABILITY of the CEAs (Ref.7).etween required performances of SR 3.1.4.3, if a CEA(s)is discovered to be immovable, the CEA is considered to be OPERABLE.At anytime, if a CEA(s)is immovable, a determination of the trippability (OPERABILITY) of that CEA(s)must be made, and appropriate action taken.CEOG STS B 3.1.4-7 Rev.3.0, 03/31/04 CEA Alignment (Digital)
B 3.1.4 BASES SURVEILLANCE REQUIREMENTS (continued) Performance of a CHANNEL FUNCTIONAL TEST of each reed switch position transmitter channel ensures the channel is OPERABLE and capable of indicating CEA position. A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay.
This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specificatio s tests at least once per refueling interval with applicable extensions.
c" Since this test must be performed when the reactor is shut down, an 18 month Frequency to be coincident with refueling outage was selected. Operating experience has shown that these components usually pass this Surveillance when performed at a Frequency of once every 18 months. Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.
+'r Verification of full length CEA drop times determines that the maximum CEA drop time permitted is consistent with the assumed drop time used in the safety analysis (Ref. 7). Measuring drop times prior to reactor criticality, after reactor vessel head removal, ensures the reactor internals and CEDM will not interfere with CEA motion or drop time, and that no degradation in these systems has occurred that would adversely affect CEA motion or drop time. Individual CEAs whose drop times are greater than safety analysis assumptions are not OPERABLE.
This SR is performed prior to criticality due to the plant conditions needed to perform the SR and the potential for an unplanned plant transient if the Surveillance were performed with the reactor at power. REFERENCES 1.
10 CFR 50, Appendix A, GDC 10 and GDC 26. 2. 10 CFR 50.46. 3. FSAR, Section
[ 1. 4. FSAR, Section
[ 1. CEOG STS B 3.1.4-8 Rev. 3.0, 03/31/04 CEA Alignment (Digital)B 3.1.4 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.1.4.4 Performance of a CHANNEL FUNCTIONAL TEST of each reed switch position transmitter channel ensures the channel is OPERABLE and capable of indicating CEA position.A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical SpecificatJgns tests at least once per refueling interval with applicable extensions.l&sect;ince this test must be performed when the reactor is shut down, an 18 month Frequency to be coincident with refueling outage was selected.Operating experience has shown that these components usually pass this Surveillance when performed at a Frequency of once every 18 months.Therefore, the Frequency was concluded to be acceptable from a reliability standpoint.-t--',,-
".InserLZ-SR 3.1.4.5 Verification of full length CEA drop times determines that the maximum CEA drop time permitted is consistent with the assumed drop time used in the safety analysis (Ref.7).Measuring drop times prior to reactor criticality, after reactor vessel head removal, ensures the reactor internals and CEDM will not interfere with CEA motion or drop time, and that no degradation in these systems has occurred that would adversely affect CEA motion or drop time.Individual CEAs whose drop times are greater than safety analysis assumptions are not OPERABLE.This SR is performed prior to criticality due to the plant conditions needed to perform the SR and the potential for an unplanned plant transient if the Surveillance were performed with the reactor at power.REFERENCES 1.10 CFR 50, Appendix A, GOC 10 and GOC 26.2.10 CFR 50.46.3.FSAR, Section[].4.FSAR, Section[].CEOG STS B 3.1.4-8 Rev.3.0, 03/31/04 Shutdown CEA Insertion Limits (Digital)
B 3.1.5 BASES SURVEILLANCE SR 3.1.5.1 REQUIREMENTS Verification that the shutdown CEAs are within their insertion limits prior to an approach to criticality ensures that when the reactor is critical, or being taken critical, the shutdown CEAs will be available to shut down the reactor, and the required SDM will be maintained following a reactor trip. This SR and Frequency ensure that the shutdown CEAs are withdrawn before the regulating CEAs are withdrawn during a unit startup.
Gnce the shutdown CEAs are positioned manually by the control room operator, verification of shutdown CEA position at a Frequency of 12 hours is adequate to ensure that the shutdown CEAs are within their insertion limits. Also, the Frequency takes into account other information available to the operator in the control room for the purpose of monitoring the status of the shutdown CEAs. 4 . ... %. _* - ""*--/ CI.m-----%....
* u REFERENCES
: 1. 10 CFR 50. Appendix A, GDC 10 and GDC 26. 2. 10 CFR 50.46. 3. FSAR, Section [ 1. CEOG STS Rev. 3.0, 03131104 BASES SURVEILLANCE REQUIREMENTS REFERENCES Shutdown CEA Insertion Limits (Digital)B 3.1.5 SR 3.1.5.1 Verification that the shutdown CEAs are within their insertion limits prior to an approach to criticality ensures that when the reactor is critical, orbeingtaken critical, the shutdown CEAs will be available to shut down the reactor, and the required SOM will be maintained following a reactor trip.This SR and Frequency ensure that the shutdown CEAs are withdrawn before the regulating CEAs are withdrawn during a unit startup. the shutdown CEAs are positioned manually by the control room operator, verification of shutdown CEA position at a Frequency of 12 hours is adequate to ensure that the shutdown CEAs are within their insertion limits.Also, the Frequency takes into account other information available to the operator in the control room for the purpose of monitoring the status of the shutdown CEAs.
h'm,.1.10 CFR 50, Appendix A, GOC 10 and 2.10 CFR 50.46.3.FSAR, Section[].CEOG STS B 3.1.5-4 Rev.3.0, 03/31/04 Regulating CEA Insertion Limits (Digital)
B 3.1.6 BASES ACTIONS (continued) With the PDIL circuit inoperable, performing SR 3.1.6.7 within 1 hour and every 4 hours thereafter ensures improper CEA alignments are identified before unacceptable flux distributions occur.
When a Required Action cannot be completed within the required Completion Time, a controlled shutdown should be commenced. The allowed Completion Time of 6 hours is reasonable, based on operating experience, for reaching MODE 3 from full power conditions in an orderly manner and without challenging plant systems.
SURVEILLANCE SR 3.1.6.1 REQUIREMENTS With the PDlL alarm circuit OPERABLE, verification of each regulating CEA group positio<evelrS/'12 hbuais sufficient to detect CEA positions that may approach the acceptable limits, and provides the operator with time to undertake the Required Action(s) should the sequence or insertion limits be found to be exceeded.De 12 hour Frequency also takes into account the indication provided by the PDlL alarm circuit and other information about CEA to the operator in the control room.
SR 3.1.6.1 is modified by a Note indicating that entry is allowed into MODE 2 for 12 hours without having performed the SR. This is necessary, since the unit must be in the applicable MODES in order to perform Surveillances that demonstrate the LC0 limits are met. Verification of the accumulated time of CEA group insertion between the long term steady state insertion limits and the transient 'nsertion limits ensures the cumulative time limits are not exceeded.
$he 24 hour Frequency ensures the operator identifies a time limit that is being approached before it is reached. &--%-.. CEOG STS B 3.1.6-7 Rev. 3.0, 03/31/04 Regulating CEA Insertion Limits (Digital)B 3.1.6 BASES ACTIONS (continued)
With the PDIL circuit inoperable.
performing SR 3.1.6.1 within 1 hour and every 4 hours thereafter ensures improper CEA alignments are identified before unacceptable flux distributions occur.When a Required Action cannot be completed within the required Completion Time, a controlled shutdown should be commenced.
The allowed Completion Time of 6 hours is reasonable, based on operating experience, for reaching MODE 3 from full power conditions in an orderly manner and without challenging plant systems.SURVEILLANCE REQUIREMENTS SR 3.1.6.1 With the PDIL alarm circuit OPERABLE, verification of each regulating CEA group positior(even'11 sufficient to detect CEA positions that may approach the acceptable limits, and provides the operator with time to undertake the Required Action(s)should the sequence or insertion limits be found to be exceeded.[!he 12 hour Frequency also takes into account the indication provided by the PDIL alarm circuit and other information about CEA. ositions available to the operator in the control room.f----.-.I-----SR 3.1.6.1 is modified by a Note indicating that entry is allowed into MODE 2 for 12 hours without having performed the SR.This is necessary, since the unit must be in the applicable MODES in order to perform Surveillances that demonstrate the LCO limits are met.SR 3.1.6.2 Verification of the accumulated time of CEA group insertion between the long term steady state insertion limits and the limits ensures the cumulative time limits are not exceeded./lhe 24 hour Frequency ensures the operator identifies a time limit that is being approached before it is reached.k-***'***"".
__-," I rl5 e!".1-..c.J CEOG STS B 3.1.6-7 Rev.3.0, 03/31/04 Regulating CEA Insertion Limits (Digital)
B 3.1.6 BASES SURVEILLANCE REQUIREMENTS (continued)
Demonstrating the PDlL alarm circuit OPERABLE verifies that the PDIL alarm circuit is functional.
Ehe 31 day Frequency takes into account other Surveillances being performed at shorter Frexencies
_mrA that identify improper CEA alignments.
~'-\+rm - REFERENCES
: 1. 10 CFR 50, Appendix A, GDC 10 and GDC 26. 2. 10 CFR 50.46. 3. FSAR, Section
[ 1, Section [ 1, and Section [ 1. 4. FSAR, Section [ 1. 5. FSAR, Section
[ 1. 6. FSAR, Section [ 1. 7. FSAR, Section
[ 1. 8. FSAR, Section
[ 1. CEOG STS Rev. 3.0, 03/31/04 Regulating CEA Insertion Limits (Digital)B 3.1.6 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.1.
 
==6.3 REFERENCES==
 
Demonstrating the PDIL alarm circuit OPERABLE verifies that the PDIL alarm circuit is functional.
[he 31 day Frequency takes into account other Surveillances being performed at shorter that identify improper GEA alignments.
..(rn........,:;_1.10 GFR 50, Appendix A, GDG 10 and GDG 26.2.10 CFR 50.46.3.FSAR, Section[], Section[], and Section[].4.FSAR, Section[].5.FSAR, Section[].6.FSAR, Section[].7.FSAR, Section[].8.FSAR, Section[].CEOG STS B 3.1.6-8 Rev.3.0, 03/31/04 Part Length CEA Insertion Limits (Digital)
B 3.1.7 BASES ACTIONS (continued)
When a Required Action cannot be completed within the required Completion Time, a controlled shutdown should commence.
A Completion Time of 4 hours is reasonable, based on operating experience, for reducing power to 5 20 RTP from full power conditions in an orderly manner and without challenging plant systems.
SURVEILLANCE SR 3.1.7.1 REQUIREMENTS Verification of each part length CEA group  position^^^
is sufficient to detect CEA positions that may approach the limits, and provide the operator with time to undertake the Required Action(s), should insertion limits be found to be exceeded.
Ehe 12 hour Frequency also takes into account the indication provided by the power dependent insertion limit alarm circuit and other information about CEA group positions available to the operator in the control REFERENCES I. 10 CFR 50, Appendix A, GDC 10 and GDC 26. 2. 10 CFR 50.46. 3. FSAR, Section
[ 1. 4. FSAR. Section I 1. CEOG STS Rev. 3.0, 03/31/04 Part Length CEA Insertion Limits (Digital)B 3.1.7 BASES ACTIONS (continued)
When a Required Action cannot be completed within the required Completion Time, a controlled shutdown should commence.A Completion Time of 4 hours is reasonable, based on operating experience, for reducing power to s 20 RTP from full power conditions in an orderly manner and without challenging plant systems.SR 3.1.7.1 10 CFR 50, Appendix A, GDC 10 and GDC 26.Verification of each part length CEA groupis sufficient to detect CEA positions that may approach the limits, and provide the operator with time to undertake the Required Action(s), should insertion limits be found to be exceeded.[he 12 hour Frequency also takes into account the indication provided by the power dependent insertion limit alarm circuit and other information about CEA group positions available to the operator in the control room. 1.SURVEILLANCE REQUIREMENTS REFERENCES 2.10 CFR 50.46.3.FSAR, Section[].4.FSAR, Section[].CEOG STS B 3.1.7-4 Rev.3.0, 03/31/04 STE - SDM (Digital)
B 3.1.8 BASES LC0 This LC0 provides that a minimum amount of CEA worth is immediately available for reactivity control when CEA worth measurement tests are performed. This STE is required to permit the periodic verification of the actual versus predicted worth of the regulating and shutdown CEAs. The SDM requirements of LC0 3.1.1, the shutdown CEA insertion limits of LC0 3.1.5, and the regulating CEA insertion limits of LC0 3.1.6 may be suspended.
APPLICABILITY This LC0 is applicable in MODES 2 and 3. Although CEA worth testing is conducted in MODE 2, sufficient negative reactivity is inserted during the performance of these tests to result in temporary entry into MODE
: 3. Because the intent is to immediately return to MODE 2 to continue CEA worth measurements, the STE allows limited operation to 6 consecutive hours in MODE 3 as indicated by the Note, without having to borate to meet the SDM requirements of LC0 3.1 .I. ACTIONS With any CEA not fully inserted and less than the minimum required reactivity equivalent available for insertion, or with all CEAs inserted and the reactor subcritical by less than the reactivity equivalent of the highest worth withdrawn CEA, restoration of the minimum SDM requirements must be accomplished by increasing the RCS boron concentration.
The required Completion Time of 15 minutes for initiating boration allows the operator sufficient time to align the valves and start the boric acid pumps and is consistent with the Completion Time of LC0 3.1 .I. SURVEILLANCE SR 3.1.8.1 REQUIREMENTS Verification of the position of each partially or fully withdrawn full length or part length CEA is necessary to ensure that the minimum ne ative reactivity requirements for insertion on a trip are preserved.
f A 2 hour Frequency is sufficient for the operator to verify that each CEA position is within the acceptance criteria.
<- @=:a Prior demonstration that each CEA to be withdrawn from the core during PHYSICS TESTS is capable of full insertion, when tripped from at least a 50% withdrawn position, ensures that the CEA will insert on a trip signal. The Frequency ensures that the CEAs are OPERABLE prior to reducing SDM to less than the limits of LC0 3.1 .I. CEOG STS Rev. 3.0, 03/31/04 BASES LCO APPLICABILITY ACTIONS SURVEILLANCE REQUIREMENTS STE-SDM (Digital)B 3.1.8 This LCO provides that a minimum amount of CEA worth is immediately available for reactivity control when CEA worth measurement tests are performed.
This STE is required to permit the periodic verification of the actual versus predicted worth of the regulating and shutdown CEAs.The SOM requirements of LCO 3.1.1, the shutdown CEA insertion limits of LCO 3.1.5, and the regulating CEA insertion limits of LCO 3.1.6 may be suspended.
This LCO is applicable in MODES 2 and 3.Although CEA worth testing is conducted in MODE 2, sufficient negative reactivity is inserted during the performance of theseteststo result in temporary entry into MODE 3.Because the intent is to immediately return to MODE 2 to continue CEA worth measurements, the STE allows limited operation to 6 consecutive hours in MODE 3 as indicated by the Note, without having to borate to meet the SDM requirements of LCO 3.1.1.With any CEA not fully inserted and less than the minimum required reactivity equivalent available for insertion, or with all CEAs inserted and the reactor subcritical by less than the reactivity equivalent of the highest worth withdrawn CEA, restoration of the minimum SDM requirements must be accomplished by increasing the RCS boron concentration.
The required Completion Time of 15 minutes for initiating boration allows the operator sufficient time to align the valves and start the boric acid pumps and is consistent withtheCompletion Time of LCO 3.1.1.SR 3.1.8.1 Verification of the position of each partially or fully withdrawn full length or part length CEA is necessary to ensure that the minimum reactivity requirements for insertion on a trip are preserved.16 2 hour Frequency is sufficient for the operator to verify that each CEA position is within the acceptance criteria.<'-(f;.--t i)J-nser.SR 3.1.8.2 Prior demonstration that each CEA to be withdrawn from the core during PHYSICS TESTS is capable of full insertion, when tripped from at least a 50%withdrawn position, ensures that the CEA will insert on a trip signal.The Frequencyensuresthat the CEAs are OPERABLE prior to reducing SDM to less than the limits of LCO 3.1.1.CEOG STS B 3.1.8-4 Rev.3.0, 03/31/04 STE - MODES 1 and 2 (Digital)
B 3.1.9 BASES SURVEILLANCE SR 3.1.9.1 REQUIREMENTS Verifying that THERMAL POWER is equal to or less than that allowed by the test power plateau, as specified in the PHYSICS TEST procedure and required by the safety analysis, ensures that adequate LHR and departure from nucleate boiling ratio margins are maintained while LCOs are suspended.
(&e 1 hour Frequency is sufficient, based upon the slow rate of power change and increased operational controls in place during PHYSICS TESTS. Monitoring LHR ensures that the limits are not exceeded.
+_C_C__.I_U_I_U_.
-- REFERENCES I. 10 CFR 50, Appendix B, Section XI. (=id7 2. 10 CFR 50.59. 3. Regulatory Guide 1.68, Revision 2, August 1978. 4. ANSIIANS-19.6.1-1985, December 13, 1985. 5. FSAR, Chapter [14]. 6. FSAR, Section [I 5.3.2. I]. 7. 10 CFR 50.46. CEOG STS Rev. 3.0, 03/31/04 STE-MODES 1 and 2 (Digital)B 3.1.9 BASES SR 3.1.9.1 10 CFR 50, Appendix B, Section XI.
1.Verifying that THERMAL POWER is equal to or less than that allowed by the test power plateau, as specified in the PHYSICS TEST procedure and required by the safety analysis, ensures that adequate lHR and departure from nucleate boiling ratio margins are maintained while LCOs are suspended.IT.he 1 hour Frequency is sufficient, based upon the slow rate of power change and increased operational controls in place during PHYSICS TESTS.Monitoring LHR ensures that the limits are not exceeded.<:----------
__.__.......REFERENCES SURVEILLANCE REQUIREMENTS 2.10 CFR 50.59.3.Regulatory Guide 1.68, Revision 2, August 1978.4.ANSI/ANS-19.6.1-1985, December 13,1985.5.FSAR, Chapter[14].6.FSAR, Section[15.3.2.1].
7.10 CFR 50.46.CEOG STS B 3.1.9-5 Rev.3.0, 03/31/04 LHR (Analog)
B 3.2.1 BASES SURVEILLANCE A Note was added to the SRs to require LHR to be determined by REQUIREMENTS either the Excore Detector Monitoring System or the lncore Detector Monitoring System.
Performance of this SR verifies that the Excore Detector Monitoring System can accurately monitor the LHR. Therefore, this SR is only applicable when the Excore Detector Monitoring System is being used to determine the LHR.
The 31 day Frequency is appropriate for this SR because it is consistent with the requirements of SR 3.3.1.3 for calibration of the excore detectors using the incore detectors.
*+-, The SR is modified by a Note that states that the SR is only required to be met when the Excore Detection Monitoring System is being used to determine LHR. The reason for the Note is that the excore detectors input neutron flux information into the AS1 calculation.
SR 3.2.1.2 and SR 3.2.1.3 Continuous monitoring of the LHR is provided by the lncore Detector Monitoring System and the Excore Detector Monitoring System. Either of these two core power distribution monitoring systems provides adequate monitoring of the core power distribution and is capable of verifying that the LHR does not exceed its specified limits.
Performance of these SRs verifies that the lncore Detector Monitoring System can accurately monitor LHR. Therefore, they are only applicable when the lncore Detector Monitoring System is being used to determine the LHR. A 31 day Frequency is consis he reactor monitoring syste C Note 1 allows the SRs to be Monitoring System is being used to determine LHR. Note 2 states that the SRs are not required to be performed when THERMAL POWER is < 20% RTP. The accuracy of the neutron flux information from the incore detectors is not reliable at THERMAL POWER < 20% RTP. CEOG STS B 3.2.1-5 Rev. 3.0, 03/31/04 BASES SURVEILLANCE REQUIREMENTS LHR (Analog)B 3.2.1 A Note was added to the SRs to require LHR to be determined by either the Excore Detector Monitoring System or the Incore Detector Monitoring System.SR 3.2.1.1 Performance of this SR verifies that the Excore Detector Monitoring System can accurately monitor the LHR.Therefore, this SR is only applicable when the Excore Detector Monitoring System is being used to determine the LHR.[he 31 day Frequency is appropriate for this SR because it is consistent with the requirements of SR 3.3.1.3 for calibration of the excore detectors using the incore detectors.
The SR is modified by a Note that states that the SR is only required to be met when the Excore Detection Monitoring System is being used to determine LHR.The reason for the Note is that the excore detectors input neutron flux information into the ASI calculation.
SR 3.2.1.2 and SR 3.2.1.3 Continuous monitoring of the LHR is provided by the Incore Detector Monitoring System and the Excore Detector Monitoring System.Either of these two core power distribution monitoring systems provides adequate monitoring of the core power distribution and is capable of verifying that the LHR does not exceed its specified limits.Performance of these SRs verifies that the Incore Detector Monitoring System can accurately monitor LHR.Therefore, they are only applicable when the Incore Detector Monitoring System is being used to determine the LHR.rA31 day Frequency is consistent with the historical testin fre uenc of reactor monitoring system.he s are mo I Ie by two Notes.Note 1 allows the SRs to be met only when the Incore Detector Monitoring System is being used to determine LHR.Note 2 states that the SRs are not required to be performed when THERMAL POWER is<20%RTP.The accuracy of the neutron flux information from the incore detectors is not reliable at THERMAL POWER<20%RTP.
CEOG STS B 3.2.1-5 Rev.3.0, 03/31/04 FL (Analog) B 3.2.2 BASES ACTIONS (continued)
If F,T cannot be returned to within its limit, THERMAL POWER must be reduced. A change to MODE 2 provides reasonable assurance that the core is operating within its thermal limits and places the core in a conservative condition.
The allowed Completion Time of 6 hours is reasonable, based on operating experience, to reach MODE 2 from full power conditions in an orderly manner and without challenging plant systems. SURVEILLANCE SR 3.2.2.1 REQUIREMENTS The periodic Surveillance to determine the calculatad F:~ ensures that FA remains within the range assumed in the analysis throughout the fuel cycle. Determining the measured F& after each fuel loading prior to the reactor exceeding 70% RTP ensures that the core is properly loaded.
c~erforrnance of the Surveillance every 31 days of accumulated operation in MODE 1 provides reasonable assurance that unacceptable changes in the FL are promptly detected.
&**> The power distribution map can only be obtained after THERMAL POWER exceeds 20%
RTP because the incore detectors are not reliable below 20% RTP. The SR is modified by a Note that requires that SR 3.2.2.2 and SR 3.2.2.3 be completed each time SR 3.2.1 .I is completed. (Values computed by these SRs are required to perform SR 3.2.2.1.)
The Note also requires that the incore detectors be used to determine Fh by using them to obtain a power distribution map with all full length CEAs above the long term steady state insertion limits, as specified in the COLR. SR 3.2.2.2 and SR 3.2.2.3 Measuring the value of Fxy and T, each time a calculated value of F& is required ensures that the calculated value of F& accurately reflects the condition of the core. CEOG STS B 3.2.2-5 Rev. 3.0, 03/31/04 Fky (Analog)B 3.2.2 BASES ACTIONS (continued)If F,T cannot be returned to within its limit, THERMAL POWER must be reduced.A change to MODE 2 provides reasonable assurance that the core is operating within its thermal limits and places the core in a conservative condition.
The allowed Completion Time of 6 hours is reasonable, based on operating experience, to reach MODE 2 from full power conditions in an orderly manner and without challenging plant systems.SURVEILLANCE SR 3.2.2.1 REQUIREMENTS The periodic Surveillance to determine the calculated Fky ensures that FIv remains within the range assumed in the analysis throughout the fuel cycle.Determining the measuredafter each fuel loading prior to the reactor exceeding 70%RTP ensures that the core is properly loaded.CPerformance of the Surveillance every 31 days of accumulated operation in MODE 1 provides reasonable assurance that unacceptable changes in the Fh are promptlyt*2'The power distribution map can only be obtained after THERMAL POWER exceeds 20%RTP because the incore detectors are not reliable below 20%RTP.The SR is modified by a Note that requires that SR 3.2.2.2 and SR 3.2.2.3 be completed each time SR 3.2.1.1 is completed.(Values computed by these SRsare required to perform SR 3.2.2.1.)The Note also requires that the incore detectors be used to determineby using them to obtain a power distribution map With all full length CEAs above the long term steady state insertion limits, as specified in the COLR.SR 3.2.2.2 and SR 3.2.2.3 Measuring the value of F xy and T q each time a calculated value ofis required ensures that the calculated value ofaccurately reflects the condition of the core.CEOG STS B 3.2.2-5 Rev.3.0, 03/31/04 F;~ (Analog) B 3.2.3 BASES ACTIONS (continued)
If F: cannot be returned to within its limit, THERMAL POWER must be reduced. A change to MODE 2 provides reasonable assurance that the core is operating within its thermal limits and places the core in a conservative condition.
The allowed Completion Time of 6 hours is reasonable, based on operating experience, to reach MODE 2 from full power conditions in an orderly manner and without challenging plant systems. SURVEILLANCE SR 3.2.3.1 REQUIREMENTS The periodic Surveillance to determine the calculated F: ensures that F: remains within the range assumed in the analysis throughout the fuel cycle. Determining the measured F: once after each fuel loading prior to exceeding 70% RTP ensures that the core is properly loaded.
c~erformance of the Surveillance every 31 days of accumulated operation in MODE - 1 provides reasonable assurance that unacceptable changes in the FT are promptly detected.
-@r+3 The power distribution map can only be obtained after THERMAL POWER exceeds 20% RTP because the incore detectors are not reliable below 20% RTP. The SR is modified by a Note that requires SR 3.2.3.2 and SR 3.2.3.3 be completed each time SR 3.2.3.1 is completed. This procedure is required because the values computed by these SRs are required to perform this SR. SR 3.2.3.2 and SR 3.2.3.3 Measuring the values of F,T and T, each time a value of F: is calculated ensures that the calculated value of FrT accurately reflects the condition of the core. The Frequency for these Surveillances is in accordance with the requirements of SR 3.2.3.1 because these SRs provide information to complete SR 3.2.2. I. CEOG STS B 3.2.3-5 Rev. 3.0, 03/31/04 F*v (Analog)B 3.2.3 BASES ACTIONS (continued) 8.1 If FrT cannot be returned to within its limit, THERMAL POWER must be reduced.A change to MODE 2 provides reasonable assurance that the core is operating within its thermal limits and places the core in a conservative condition.
The allowed Completion Time of 6 hours is reasonable, based on operating experience, to reach MODE 2 from full power conditions in an orderly manner and without challenging plant systems.SURVEILLANCE SR 3.2.3.1 REQUIREMENTS The periodic Surveillance to determine the calculated Fl ensures that F,T remains within the range assumed in the analysis throughout the fuel cycle.Determining the measured F,T once after each fuel loading prior to exceeding 70%RTP ensures that the core is properly loaded.[performance of the Surveillance every 31 days of accumulated operation in MODE 1 provides reasonable assurancethatunacceptable changes in theare promptly detected.The power distribution map can only be obtained after THERMAL POWER exceeds 20%RTP because the incore detectors are not reliable below 20%RTP.The SR is modified by a Note that requires SR 3.2.3.2 and SR 3.2.3.3 be completed each time SR 3.2.3.1 is completed.
This procedure is required because the values computed by these SRs are required to perform this SR.SR 3.2.3.2 and SR 3.2.3.3 Measuring the values of Fl and T q each time a value of Fl is calculated ensures that the calculated value of F,T accurately reflects the condition of the core.The Frequency for these Surveillances is in accordance with the requirements of SR 3.2.3.1 because these SRs provide information to complete SR 3.2.2.1.CEOG STS B 3.2.3-5 Rev.3.0, 03/31/04 T, (Analog) B 3.2.4 BASES ACTIONS (continued) modified with a Note to indicate that the cause of the out of limit condition must be corrected prior to increasing THERMAL POWER. This Note also indicates that subsequent power operation above 50% RTP may proceed provided that the measured T, is verified 5 [0.03] at least once per hour for 12 hours, or until verified at 95% RTP. This ensures that the power distribution is responding as predicted.
The Completion Time of 12 hours is a historical value that allows an acceptable exit from the LC0 after the T, value is verified acceptable for 12 hours or until 95% RTP is reached.
SURVEILLANCE SR 3.2.4.1 REQUIREMENTS Eq must be calculated at 12 hour intervals. The 12 hour Frequency prevents significant xenon redistribution between REFERENCES
: 1. FSAR, Chapter [I 51. ,*,w'mWW--ilA
: 2. FSAR, Chapter [6]. 3. 10 CFR 50, Appendix A. 4. 10 CFR 50. CEOG STS Rev. 3.0, 03/31/04 T q (Analog)B 3.2.4 BASES ACTIONS (continued) modified with a Note to indicate that the cause of the out of limit condition must be corrected prior to increasing THERMAL POWER.This Note also indicates that subsequent power operation above 50%RTP may proceed provided that the measured T q is verified:5[0.03]at least once per hour for 12 hours, or until verified at 95%RTP.This ensures that the power distribution is responding as predicted.
The Completion Time of 12 hours is a historical value that allows an acceptable exit from the LCD after the T q value is verified acceptable for 12 hours or until 95%RTP is reached.1.FSAR, Chapter[15].GE..
2.FSAR, Chapter[6].SR 3.2.4.1[Jq must be calculated at 12 hour intervals.
The 12 hour Frequency prevents significant xenon redistribution between Surveillances.
REFERENCES SURVEILLANCE REQUIREMENTS 3.10 CFR 50, Appendix A.4.10 CFR 50.CEOG STS B 3.2.4-6 Rev.3.0, 03/31104 AS1 (Analog) B 3.2.5 BASES ACTIONS (continued)
If the AS1 cannot be restored to within its specified limits, or AS1 cannot be determined because of Excore Detector Monitoring System inoperability, core power must be reduced. Reducing THERMAL POWER to 120% RTP provides reasonable assurance that the core is operating farther from thermal limits and places the core in a conservative condition. Four hours is a reasonable amount of time, based on operating experience, to reduce THERMAL POWER to 5 20% RTP in an orderly manner and without challenging plant systems. SURVEILLANCE SR 3.2.5.1 REQUIREMENTS Verifying that the AS1 is within the specified limits provides reasonable assurance that the core is not approaching DNB conditions.
E~re~uenc~
of 12 hours is adequate for the operator to identify trends in conditions that result in an approach to the AS1 limits, because the mechanisms that affect the ASI, such as xenon redistribution or CEA drive mechanism malfunctions, cause the AS1 to change slowly and should be discovered before the limits are exceeded.
+- -C e REFERENCES
: 1. FSAR, Chapter [I 51. (3me.. 2. FSAR, Chapter [6]. 3. 10 CFR 50, Appendix A.
: 4. 10 CFR 50.46. CEOG STS Rev. 3.0, 03/31/04 ASI{Analog}B 3.2.5 BASES ACTIONS{continued}
If the ASI cannot be restored to within its specified limits, or ASI cannot be determined because of Excore Detector Monitoring System inoperability, core power must be reduced.Reducing THERMAL POWER to$20%RTP provides reasonable assurance that the core is operating farther from thermal limits and places the core in a conservative condition.
Four hours is a reasonable amount of time, based on operating experience, to reduce THERMAL POWER to$20%RTP in an orderly manner and without challenging plant systems.SURVEILLANCE REQUIREMENTS SR 3.2.5.1 1.FSAR, Chapter[15].
Verifying that the ASI is within the specified limits provides reasonable assurance that the core is not approaching DNB conditions.Frequency of 12 hours is adequate for the operator to identify trends in conditions that result in an approach to the ASI limits, because the mechanisms that affect the ASI, such as xenon redistribution or CEA drive mechanism malfunctions, cause the ASI to change slowly and should be discovered before the limits are exceeded.REFERENCES 2.FSAR, Chapter[6].3.10 CFR 50, Appendix A.4.10 CFR 50.46.CEOG STS B 3.2.5-5 Rev.3.0, 03/31/04 LHR (Digital)
B 3.2.1 BASES ACTIONS (continued) change in the CPC calculated LHR ensures that further degradation requires the operators to take immediate action to restore LHR to within limits or reduce reactor power to comply with the Technical Specifications (TS). With an adverse trend, 1 hour is allowed for restoring LHR to within limits if the COLSS is not restored to OPERABLE status. Implementation of this requirement ensures that reductions in core thermal margin are quickly detected, and if necessary, results in a decrease in reactor power and subsequent compliance with the existing COLSS out of service TS limits. With no adverse trend, 4 hours is allowed to restore the LHR to within limits if the COLSS is not restored to OPERABLE status. This duration is reasonable because the Frequency of the CPC determination of LHR is increased and if operation is maintained steady, the likelihood of exceeding the LHR limit during this period is not increased.
The likelihood of induced reactor transients from an early power reduction is also decreased.
If the LHR cannot be returned to within its limit or the LHR cannot be determined because of the COLSS and CPC inoperability, core power must be reduced. Reduction of core power to c 20% RTP ensures that the core is operating within its thermal limits and places the core in a conservative condition based on the trip setpoints generated by the CPCs, which assume a minimum core power of 20% RTP. The allowed Completion Time of 6 hours is reasonable, based on operating experience, to reach 20% RTP in an orderly manner and without challenging plant systems. SURVEILLANCE SR 3.2.1.1 REQUIREMENTS With the COLSS out of service, the operator mus monitor the LHR with each OPERABLE local power density channel.
I? A 2 hour Frequency is sufficient to allow the o~erator to identifv trends that would result in an approach to the LHR limits. e--. This SR is modified by a Note that states that the SR is only required to be met when the COLSS is out of service. Continuous monitoring of the LHR is provided by the COLSS, which calculates core power and core power operating limits based on the LHR and continuously displays these limits to the operator. A COLSS margin alarm is annunciated in the event that the THERMAL POWER exceeds the core power operating limit based on LHR. CEOG STS B 3.2.1-6 Rev. 3.0, 03/31/04 LHR (Digital)B 3.2.1 BASES ACTIONS (continued) change in the CPC calculated LHR ensures that further degradation requires the operators to take immediate action to restore LHR to within limits or reduce reactor power to comply with the Technical Specifications (TS).With an adverse trend, 1 hour is allowed for restoring LHR to within limits if the COLSS is not restored to OPERABLE status.Implementation of this requirement ensures that reductions in core thermal margin are quickly detected, and if necessary, results in a decrease in reactor power and subsequent compliance with the existing COLSS out of service TS limits.With no adverse trend, 4 hours is allowed to restore the LHR to within limits if the COLSS is not restored to OPERABLE status.This duration is reasonable because the Frequency of the CPC determination of LHR is increased and if operation is maintained steady, the likelihood of exceeding the LHR limit during this period is not increased.
The likelihood of induced reactor transients from an early power reduction is also decreased.
If the LHR cannot be returned to within its limit or the LHR cannot be determined because of the COLSS and CPC inoperability, core power must be reduced.Reduction of core power to<20%RTP ensures that the core is operating within its thermal limits and places the core in a conservative condition based on the trip setpoints generated by the CPCs, which assume a minimum core power of 20%RTP.The allowed Completion Time of 6 hours is reasonable, based on operating experience, to reach 20%RTP in an orderly manner and without challenging plant systems.SURVEILLANCE REQUIREMENTS SR 3.2.1.1 With the COLSS out of service, the operator mu.&sect;1 monitor the LHR with each OPERABLE local power density channel.lA 2 hour Frequency is sufficient to allow the operator to identify trends that would result in an approach to the LHR limits.
t'This SR is modified by a Note that states that the SR is only required to be met when the COLSS is out of service.Continuous monitoring of the LHR is provided by the COLSS, which calculates core power and core power operating limits based on the LHR and continuously displays these limits to the operator.A COLSS margin alarm is annunciated in the event that the THERMAL POWER exceeds the core power operating limit based on LHR.CEOG STS B 3.2.1-6 Rev.3.0, 03/31/04 LHR (Digital) 6 3.2.1 BASES SURVEILLANCE REQUIREMENTS (continued)
Verification that the COLSS margin alarm actuates at a THERMAL POWER level equal to or less than the core power operating limit based on the LHR in units of kilowatts per foot ensures the operator is alerted when conditions approach the LHR operating limit.
Eie 31 day Frequency for performance of this SR is consistent with the historical testing frequency of reactor protection and monitoring systems. The Surveillance Frequency for testing protection systems was extended to 92 days by CEN 327. Monitoring systems were not addressed in 2. FSAR, Section [6]. 3. CE-1 Correlation for DNBR. 4. 10 CFR 50.46, Appendix A, GDC 10 5. 10 CFR 50.46. CEOG STS Rev. 3.0, 03131104 LHR (Digital)B 3.2.1 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.2.1.2 1.FSAR, Section[15].
2.FSAR, Section[6].Verification that the COLSS margin alarm actuates at a THERMAL POWER level equal to or less than the core power operating limit based on the LHR in units of kilowatts per foot ensures the operator is alerted when conditions approach the LHR operating limit.[[he 31 day Frequency for performance of this SR is consistent with the historical testing frequency of reactor protection and monitoring systems.The Surveillance Frequency for testing protection systems was extended to 92 days by CEN 327.Monitoring systems were not addressed in CEN 327;therefore, this Frequency remains at 31 days.
REFERENCES 3.CE-1 Correlation for DNBR.4.10 CFR 50.46, Appendix A, GDC 10.5.10 CFR 50.46.CEOG STS B 3.2.1-7 Rev.3.0, 03/31/04 FXy (Digital)
B 3.2.2 BASES ACTIONS (continued)
If Required Actions A.l .I and A.1.2 or A.2 cannot be accomplished within 6 hours, the core power must be reduced. Reduction to 20% RTP or less ensures that the core is operating within the specified thermal limits and places the core in a conservative condition based on the trip setpoints generated by the COLSS and CPC operating limits; these limits are established assuming a minimum core power of 20% RTP. Six hours is a reasonable time to reach 20% RTP in an orderly manner and without challenging plant systems.
SURVEILLANCE SR 3.2.2.1 REQUIREMENTS This periodic Surveillance is for determining, using the lncore Detector System, that F,M, values are I F& values used in the COLSS and CPCs. It ensures that the F& values used remain valid throughout the fuel cycle.
d Frequency of 31 EFPD is acceptable because the changes only slightly with the amount of fuel burnup 2. FSAR, Section [6]. 3. CE-1 Correlation for DNBR.
: 4. 10 CFR 50.46, Appendix A, GDC 10. 5. I0 CFR 50.46. CEOG STS Rev. 3.0, 03/31/04 F xy (Digital)B 3.2.2 BASES ACTIONS (continued)
If Required Actions A.1.1 and A.1.2 or A.2 cannot be accomplished within 6 hours, the core power must be reduced.Reduction to 20%RTP or less ensures that the core is operating within the specified thermal limits and places the core in a conservative condition based on the trip setpoints generated by the COLSS and CPC operating limits;these limits are established assuming a minimum core power of 20%RTP.Six hours is a reasonable time to reach 20%RTP in an orderly manner and without challenging plant systems.SR 3.2.2.1 1.FSAR, Section[15].This periodic Surveillance is for determining, using the Incore Detector System, that values are=::;F;y values used in the COLSS and CPCs.It ensures that the F;y values used remain valid throughout the fuel cycle.Frequency of 31 EFPD is acceptable because the power distributio changes only slightly with the amount of fuel burnup.Determining the values after each fue/loading when THERMAL POWER is>40%RTP, but prior to its exceeding 70%RTP, ensures that the core is properly loaded.SURVEILLANCE REQUIREMENTS REFERENCES 2.FSAR, Section[6].3.CE-1 Correlation for DNBR.4.10 CFR 50.46, Appendix A, GDC 10.5.10 CFR 50.46.CEOG STS B 3.2.2-6 Rev.3.0, 03/31/04 T, (Digital)
B 3.2.3 BASES ACTIONS (continued)
The provision to allow discontinuation of the Surveillance after verifying that TQ S 0.10 is within its specified limit at least once per hour for 12 hours or until TQ is verified to be within its specified limit at a THERMAL POWER 2 95% RTP provides an acceptable exit from this action after the measured TQ has been returned to an acceptable value. If the measured TQ cannot be restored or determined within its specified limit, core power must be reduced. Reduction of core power to
< 20% RTP ensures that the core is operating within its thermal limits and places the core in a conservative condition based on the trip setpoints generated by the CPCs, which assume a minimum core power of 20% RTP. Six hours is a reasonable time to reach 20% RTP in an orderly manner and without challenging plant systems. SURVEILLANCE SR 3.2.3.1 REQUIREMENTS Continuous monitoring of the measured TQ by the incore nuclear detectors is provided by the COLSS. A COLSS alarm is annunciated in the event that the measured TO exceeds the value used in the CPCs. With the COLSS out of service, the operator must calculate TQ and verify that it is within its specified
~irnits.@e 12 hour Frequency is sufficient to identify slowly developing TQ's before they exceed the limits of this LCO.
Also, the 12 hour Frequency prevents significant xenon redist&~,uti~n,~~
:,_ Verification that the COLSS TQ alarm actuates at a value less than the value used in the CPCs ensures that the operator is alerted if TQ approaches its operating limit.
rhe 31 day Frequency for performance of this SR is consistent with the historical testing frequency of reactor protection and monitoring systems.
The Surveillance Frequency for testing protection systems was extended to 92 days by CEN 327. Monitoring systems were not addressed in CEN 327; therefore, this Frequency remains at 31 days.
CEOG STS Rev. 3.0, 03/31/04 T q (Digital)B 3.2.3 BASES ACTIONS (continued)
The provision to allow discontinuation of the Surveillance after verifying thatTa::::;0.10 is within its specified limit atleastonce per hour for 12 hours or untilTa is verified to be within its specified limit at a THERMAL POWER95%RTP provides an acceptable exit from this action after the measuredTa has been returned to an acceptable value.If the measuredTa cannot be restored or determined within its specified limit, core power must be reduced.Reduction of core power to<20%RTP ensures that the core is operating within its thermal limits and places the core in a conservative condition based on the trip setpoints generated by the CPCs, which assume a minimum core power of 20%RTP.Six hours is a reasonable time to reach 20%RTP in an orderly manner and without challenging plant systems.SURVEILLANCE REQUIREMENTS SR 3.2.3.1 Continuous monitoring of the measuredTa by the incore nuclear detectors is provided by the COLSS.A COLSS alarm is annunciated in the event that the measuredTa exceeds the value used in the CPCs.With the COLSS out of service, the operator must calculateTa and verify that it is within its specified limits.rr.he 12 hour Frequency is sufficient to identify slOWly developing T a's before they exceed the limits of this LCO.Also, the 12 hour Frequency prevents significant xenon redi C.
,...or\Ct;" r t?').,-1-..,1___
__';M>SR 3.2.3.2 Verification that the COLSS T Q alarm actuates at a value less than the value used in the CPCs ensures that the operator is alerted ifTa approaches its operating limit.[he 31 day Frequency for performance of this SR is consistent with the historical testing frequency of reactor protection and monitoring systems.The Surveillance Frequency for testing protection systems was extended to 92 days by CEN 327.Monitoring systems were not addressed in CEN 327;therefore, this Frequency remains at 31 days.
CEOG STS B 3.2.3-7 Rev.3.0, 03/31/04 T, (Digital)
B 3.2.3 BASES SURVEILLANCE REQUIREMENTS (continued)
Independent confirmation of the validity of the COLSS calculated TQ ensures that the COLSS accurately identifies Tds. Ghe 31 day Frequency for performance of this SR is consistent with the historical testing frequency of reactor protection and monitoring systems.
The Surveillance Frequency for testing protection systems was extended to 92 days by CEN 327. Monitoring systems were not addressed in CEN 327; therefore, this Frequency remains at 31 days. ew, REFERENCES I. FSAR, Section
[15]. 2. FSAR, Section [6]. 3. CE-1 Correlation for DNBR. 4. 10 CFR 50.46, Appendix A, GDC 10. 5. 10 CFR 50.46. 6. 10 CFR 50, Appendix A, GDC 26. CEOG STS Rev. 3.0, 03/31/04 T q (Digital)B 3.2.3 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.2.3.3 Independent confirmation of the validity of the COLSS calculatedTa ensures that the COLSS accurately identifies T a's.!ihe 31 day Frequency for performance of this SR is consistent with the historical testing frequency of reactor protection and monitoring systems.The Surveillance Frequency fortestingprotection systems was extended to 92 days by CEN 327.Monitoring systems were not addressed in CEN 327;therefore, this Frequency remains at 31 days.<:--REFERENCES 1.FSAR, Section[15].2.FSAR, Section[6].3.CE-1 Correlation for DNBR.4.10 CFR 50.46, Appendix A, GDC 10.5.10 CFR 50.46.6.10 CFR 50, Appendix A, GDC 26.CEOG STS B 3.2.3-8 Rev.3.0, 03/31/04 DNBR (Digital)
B 3.2.4 BASES ACTIONS (continued)
If the DNBR cannot be restored or determined within the allowed times of Conditions A and B, core power must be reduced. Reduction of core power to < 20% RTP ensures that the core is operating within its thermal limits and places the core in a conservative condition based on trip setpoints generated by the CPCs, which assume a minimum core power of 20% RTP. The allowed Completion Time of 6 hours is reasonable, based on operating experience, to reach 20% RTP from full power conditions in an orderly manner and without challenging plant systems.
SURVEILLANCE SR 3.2.4.1 REQUIREMENTS With the COLSS out of service, the operator must monitor the DNBR as indicated on any of the OPERABLE DNBR channels of the CPCs to verify that the DNBR is within the specified li~its, shown in either Figure 3.2.4-1 or 3.2.4-2 of the COLR, as applicable. 2 hour Frequency is adequate to allow the operator to identify trends in conditions that would result in an approach to the DNBR limit. 6,. . wmkhp-d This SR is modified by a Note that states that the SR is only required to be met when the COLSS is out of service. Continuous monitoring of the DNBR is provided by the COLSS, which calculates core power and core power operating limits based on the DNBR and continuously displays these limits to the operator.
A COLSS margin alarm is annunciated in the event that the THERMAL POWER exceeds the core power operating limit based on the DNBR. Verification that the COLSS margin alarm actuates at a power level equal to or less than the core power operating limit, as calculated by the COLSS, based on the DNBR, ensures that the operator is alerted when operating conditions approach the DNBR operating limit.
@e 31 day Frequency for performance of this SR is consistent with the historical testing frequency of reactor protection and monitoring systems.
T'he Surveillance Frequency for testing protection systems was extended to 92 days by CEN 327. Monitoring systems were not addressed in CEN 327; therefore, this
~re~uency remains at 31 days. CEOG STS B 3.2.4-7 Rev. 3.0, 03/31/04 DNBR (Digital)B3.2.4 BASES ACTIONS (continued)
If the DNBR cannot be restored or determined within the allowed times of Conditions A and B, core power must be reduced.Reduction of core power to<20%RTP ensures that the core is operating within its thermal limits and places the core in a conservative condition based on trip setpoints generated by the CPCs, which assume a minimum core power of 20%RTP.The allowed Completion Time of 6 hours is reasonable, based on operating experience, to reach 20%RTP from full power conditions in an orderly manner and without challenging plant systems.SURVEILLANCE REQUIREMENTS SR 3.2.4.1 With the COLSS out of service, the operator must monitor the DNBR as indicated on any of the OPERABLE DNBR channels of the CPCs to verify that the DNBR is within the specified Iirujts, shown in either Figure 3.2.4-1 or 3.2.4-2 of the COLR, as applicable.
g 2 hour Frequency is adequate to allow the operator to identify trends in conditions that would result in an approach to the DNBR limit.
This SR is modified by a Note that states that the SR is only required to be met when the COLSS is out of service.Continuous monitoring of the DNBR is provided by the COLSS, which calculates core power and core power operating limits based on the DNBR and continuously displays these limits to the operator.A COLSS margin alarm is annunciated in the event that the THERMAL POWER exceeds the core power operating limit based on the DNBR.SR 3.2.4.2 Verification that the COLSS margin alarm actuates at a power level equal to or less than the core power operating limit, as calculated by the COLSS, based on the DNBR, ensures that the operator is alerted when operating conditions approach the DNBR operating limit.IT.he 31 day Frequency for performance of this SR is consistent with the historical testing frequency of reactor protection and monitoring systems.The Surveillance Frequency for testing protection systems was extended to 92 days by CEN 327.Monitoring systems were not addressed in CEN 327;therefore, this Frequency remains at 31 days...:I: n5er"[2.)
CEOG STS B 3.2.4-7 Rev.3.0, 03/31/04 AS1 (Digital)
B 3.2.5 BASES APPLICABILITY (continued)
: b. As a result of this inaccuracy, the CPCs assume a minimum core power of 20% RTP when generating the LPD and DNBR trip signals.
When the core power is below this level, the core is operating well below the thermal limits and the resultant CPC calculated LPD and DNBR trips are strongly conservative.
ACTIONS - A.1 The AS1 limits specified in the COLR ensure that the LOCA and loss of flow accident criteria assumed in the accident analyses remain valid. If the AS1 exceeds its limit, a Completion Time of 2 hours is allowed to restore the AS1 to within its specified limit. This duration gives the operator sufficient time to reposition the regulating or part length CEAs to reduce the axial power imbalance. The magnitude of any potential xenon oscillation is significantly reduced if the condition is not allowed to persist for more than 2 hours. If the AS1 is not restored to within its specified limits within the required Completion Time, the reactor continues to operate with an axial power distribution mismatch. Continued operation in this configuration induces an axial xenon oscillation, and results in increased LHGRs when the xenon redistributes. Reducing thermal power to 5 20% RTP reduces the maximum LHR to a value that does not exceed the fuel design limits if a design basis event occurs.
The allowed Completion Time of 4 hours is reasonable, based on operating experience, to reduce power in an orderly manner and without challenging plant systems.
SURVEILLANCE SR 3.2.5.1 REQUIREMENTS The AS1 can be monitored by both the incore (COLSS) and excore (CPC) neutron detector systems.
The COLSS provides the operator with an alarm if an AS1 limit is approached. Verification of the ASI ensures that the operator is aware of changes in the AS1 as they develop.
6 12 hour Frequency for this Surveillance is acceptable because the mechanisms that affect the ASI, such as xenon redistribution or CEA drive mechanism malfunctions, cause slow changes in the ASI, which can be discovered before the limits are exceeded.
4, - CEOG STS - Rev. 3.0, 03/31/04 ASI (Digital)B 3.2.5 BASES APPLICABILITY (continued) b.As a result of this inaccuracy, the CPCs assume a minimum core power of 20%RTP when generating the LPD and DNBR trip signals.When the core power is below this level, the core is operating well below the thermal limits and the resultant CPC calculated LPD and DNBR trips are strongly conservative.
ACTIONS The ASllimits specified in the COLR ensure that the LOCA and loss of flow accident criteria assumed in the accident analyses remain valid.If the AS)exceeds its limit, a Completion Time of 2 hours is allowed to restore the ASI to within its specified limit.This duration gives the operator sufficient time to reposition the regulating or part length CEAs to reduce the axial power imbalance.
The magnitude of any potential xenon oscillation is significantly reduced if the condition is not allowed to persist for more than 2 hours.If the ASI is not restored to within its specified limits within the required Completion Time, the reactor continues to operate with an axial power distribution mismatch.Continued operation in this configuration induces an axial xenon oscillation, and results in increased LHGRs when the xenon redistributes.
Reducing thermal power to:s 20%RTP reduces the maximum LHR to a value that does not exceed the fuel design limits if a design basis event occurs.The allowed Completion Time of 4 hours is reasonable, based on operating experience, to reduce power in an orderly manner and without challengingplantsystems.
SURVEILLANCE REQUIREMENTS SR 3.2.5.1 The ASI can be monitored by both the incore (COLSS)and excore (CPC)neutron detector systems.The COLSS provides the operator with an alarm if an ASllimit is approached.
Verification of the that the operator is aware of changes in the ASI as they develop.12 hour Frequency for this Surveillance is acceptable because the mechanisms that affect the ASI, such as xenon redistribution or CEA drive mechanism malfunctions, cause slow changes in the ASI, which can be discovered before the limits are exceeded"', 1"_t'"''''Un ser.:::..1(.., CEOG STS B 3.2.5-5 Rev.3.0, 03/31/04 RPS Instrumentation - Operating (Analog)
B 3.3.1 BASES ACTIONS (continued)
Condition G is entered when the Required Action and associated Completion Time of Conditions A, B, C, D, E, or F are not met.
If the Required Actions associated with these Conditions cannot be completed within the required Completion Times, the reactor must be brought to a MODE in which the Required Actions do not apply. The allowed Completion Time of 6 hours to be in MODE 3 is reasonable, based on operating experience, for reaching the required MODE from full power conditions in an orderly manner and without challenging plant systems. SURVEILLANCE The SRs for any particular RPS Function are found in the SR column of REQUIREMENTS Table 3.3.1-1 for that Function. Most Functions are subject to CHANNEL CHECK, CHANNEL FUNCTIONAL TEST, CHANNEL CALIBRATION, and response time testing.
-------+*--------------------------
REVIEWER'S NOTE ...................................
In order for a plant to take credit for topical reports as the basis for justifying Frequencies, topical reports must be supported by an NRC staff SER that establishes the acceptability of each topical report for that plant (Ref. 9). ,*w Performance of the CHANNEL CHECK w-nsures that gross failure of instrumentation has not occurred.
A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels.
It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the two instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more serious. CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying that the instrumentation continues to operate properly between each CHANNEL CALIBRATION. Agreement criteria are determined by the plant staff based on a combination of the channel instrument uncertainties, including indication and readability. If a channel is outside the criteria, it may be an indication that the transmitter or the signal processing equipment has drifted outside its limits.
CEOG STS B 3.3.1-27 Rev. 3.0, 03/31/04 RPS Instrumentation
-Operating (Analog)B 3.3.1 BASES ACTIONS (continued)
Condition G is entered when the RequiredActionand associated Completion Time of Conditions A, B, C, D, E, or F are not met.If the Required Actions associated with these Conditions cannot be completed within the required Completion Times, the reactor must be brought to a MODE in which the Required Actions do not apply.The allowed Completion Time of 6 hours to be in MODE 3 is reasonable, based on operating experience, for reaching the required MODE from full power conditions in an orderly manner and without challenging plant systems.SURVEILLANCE REQUIREMENTS The SRs for any particular RPS Function are found in the SR column of Table 3.3.1-1 for that Function.Most Functions are subject to CHANNEL CHECK, CHANNEL FUNCTIONAL TEST, CHANNEL CALIBRATION, and response time testing.-----------------------------------REVI EWE R'S NOTE In order for a plant to take credit for topical reports as the basis for justifying Frequencies, topical reports must be supported by an NRC staff SER that establishes the acceptability of each topical report for that plant (Ref.9).SR 3.3.1.1 Performance of the CHANNEL CHECK that gross failure of instrumentation has not occurred.A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels.It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value.Significant deviations between the two instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more serious.CHANNEL CHECK will detect gross channel failure;thus, it is key to verifying that the instrumentation continues to operateproperlybetween each CHANNEL CALIBRATION.
Agreement criteria are determined by the plant staff based on a combination of the channel instrument uncertainties, including indication and readability.
If a channel is outside the criteria, it may be an indication that the transmitter or the signal processing equipment has drifted outside its limits.CEOG STS B 3.3.1-27 Rev.3.0, 03/31/04 RPS Instrumentation - Operating (Analog)
B 3.3.1 BASES SURVEILLANCE REQUIREMENTS (continued)
Ehe Frequency, about once every shift, is based on operating experience that demonstrates the rarity of channel failure. Since the probability of two random failures in redundant channels in any 12 hour period is extremely low, the CHANNEL CHECK minimizes the chance of loss of protective function due to failure of redundant channels.
The CHANNEL CHECK supplements less formal, but more frequent, checks of channel OPERABILITY during normal operational use of the displays associated with the LC0 required channels.
,+ -"I*, A daily calibration (heat balance) is performed when THERMAL POWER is 2 20%. The daily calibration shall consist of adjusting the "nuclear power calibrate" potentiometers to agree with the calorimetric calculation if the absolute difference is
> 1.5%. The "AT power calibrate" potentiometers are then used to null the "nuclear power - AT power" indicators on the RPS Reactor Power Calibration and Indication panel.
Performance of the daily calibration ensures that the two inputs to the Q power measurement are indicating accurately with respect to the much more accurate secondary calorimetric calculation.
fie Frequency of 24 hours is based on plant operating experience and - takes into account indications and alarms located in the control room to detect deviations in channel outputs.dThe Frequency is mod- Note indicating this Suweillance must be performed within 12 hours after THERMAL POWER is r 20% RTP. The secondary calorimetric is inaccurate at lower Dower levels. The 12 hours allows time reauirements for plant stabilization, data taking, and instrument calibration.
' eB A second Note indicates the daily calibration may be suspended during PHYSICS TESTS. This ensures that calibration is proper preceding and following physics testing at each plateau, recognizing that during testing, changes in power distribution and RCS temperature may render the calorimetric inaccurate.
CEOG STS 6 3.3.1-28 Rev. 3.0, 03/31/04 BASES RPS Instrumentation
-Operating (Analog)B 3.3.1 A daily calibration (heat balance)is performed when THERMAL POWER is20%.The daily calibration shall consist of adjusting the"nuclear power calibrate" potentiometers to agree with the calorimetric calculation if the absolute difference is>1.5%.The"Ll T power calibrate" potentiometers are then used to null the"nuclear power-t\T power" indicators on the RPS Reactor Power Calibration and Indication panel.Performance of the daily calibration ensures that the two inputs to the Q power measurement are indicating accurately with respect to the much more accurate secondary calorimetric calculation.
[fhe Frequency of 24 hours is based on plant operating experience and takes into account indications and alarms located in the control room to detect deviations in channel outputs.he Frequency IS mo I Ieya Note indicating this Surveillance must be performed within 12 hours after THERMAL POWER is 2: 20%RTP.The secondary calorimetric is inaccurate at lower power levels.The 12 hours allows time requirements for plant stabilization, data taking, and instrument calibration. A second Note indicates the daily calibration may be suspended during PHYSICS TESTS.This ensures that calibration is proper preceding and following physics testing at each plateau, recognizing that during testing, changes in power distribution and RCS temperature may render the calorimetric inaccurate.
CEOG STS B 3.3.1-28 Rev.3.0, 03/31/04 RPS Instrumentation - Operating (Analog)
B 3.3.1 BASES SURVEILLANCE REQUIREMENTS (continued)
It is necessary to calibrate the excore power range channel upper and lower subchannel amplifiers such that the internal AS1 used in the TMILP and APD - High trips reflects the true core power distribution as determined by the incore detectors. A Note to the Frequency indicates the Surveillance is required within 12 hours after THERMAL POWER is r [20]% RTP. Uncertainties in the excore and incore measurement process make it impractical to calibrate when THERMAL POWER is [20]% RTP. The Completion Time of 12 hours allows time for plant stabilization, data taking, and instrument calibration. If the excore detectors are not properly calibrated to agree with the incore detectors, power is restricted during subsequent operations because of increased uncertainty associated with using uncalibrated excore detectors.
Ehe 31 day Frequency is adequate, based on operating experience of the excore linear amplifiers and the slow burnup of the detectors.
The excore readings are a strong function of the power produced in the peripheral fuel bundles and do not represent an integrated reading across the core. Slow changes in neutron flux during the fuel cycle can also be detected at this Frequency.
4 ..,--_ A CHANNEL FUNCTIONAL TEST is performed on each RPS instrument channel, except Loss of Load and Power Rate of
~han~qeFm to ensure the entire channel will perform its intended function w en needed. A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
In addition to power supply tests, The RPS CHANNEL FUNCTIONAL TEST consists of three overlapping tests as described in Reference
: 8. These tests verify that the RPS is capable of performing its intended function, from bistable input through the RTCBs. They include: CEOG STS B 3.3.1-29 Rev. 3.0. 03/31/04 RPS Instrumentation
-Operating (Analog)B 3.3.1 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.1.3 It is necessary to calibrate the excore power range channel upper and lower subchannel amplifiers such that the internal ASI used in the TM/LP and APD-High trips reflects the true core power distribution as determined by the incore detectors.
A Note to the Frequency indicates the Surveillance is required within 12 hours after THERMAL POWER is 2:[20]%RTP.Uncertainties in the excore and incore measurement process make it impractical to calibrate when THERMAL POWER is<[20]%RTP.The Completion Time of 12 hours allows time for plant stabilization, data taking, and instrument calibration.
If the excore detectors are not properly calibrated to agree with the incore detectors, power is restricted during subsequent operations because of increased uncertainty associated with using uncalibrated excore detectors.
[fhe 31 day Frequency is adequate, based on operating experience of the excore linear amplifiers and the slow burnup of the detectors.
The excore readings are a strong function of the power produced in the peripheral fuel bundles and do not represent an integrated reading across the core.Slow changes in neutron flux during the fuel cycle can also be detected at thiS Frequency.
<."..
._..._"_._"'..'".....,_...."...."--_.t""-;:
..,." 0.L?I SR 3.3.1.4 A CHANNEL FUNCTIONAL TEST is performed on each RPS instrument channel, except Loss of Load and Power Rate of to ensure the entire channel will perform its intended func&nWen needed.A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay.This is acceptable because all of the other required contacts of the relay are verified by Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
In addition to power supply tests, The RPS CHANNEL FUNCTIONAL TEST consists of three overlapping tests as described in Reference 8.These tests verify that the RPS is capable of performing its intended function, from bistable input through the RTCBs.They include: CEOG STS B 3.3.1-29 Rev.3.0, 03/31/04 RPS Instrumentation - Operating (Analog)
B 3.3.1 BASES SURVEILLANCE REQUIREMENTS (continued) Bistable Tests The bistable setpoint must be found to trip within the Allowable Values specified in the LC0 and left set consistent with the assumptions of the plant specific setpoint analysis (Ref.
7). As found and as left values must also be recorded and reviewed for consistency with the assumptions of the frequency extension analysis. The requirements for this review are outlined in Reference
: 10. A test signal is superimposed on the input in one channel at a time to verify that the bistable trips within the specified tolerance around the setpoint. This is done with the affected RPS channel trip channel bypassed.
Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint analysis.
Matrix Loqic Tests Matrix Logic tests are addressed in LC0 3.3.3. This test is performed one matrix at a time.
It verifies that a coincidence in the two input channels for each Function removes power from the matrix relays. During testing, power is applied to the matrix relay test coils and prevents the matrix relay contacts from assuming their de-energized state. This test will detect any short circuits around the bistable contacts in the coincidence logic, such as may be caused by faulty bistable relay or trip channel bypass contacts. Trip Path Tests Trip Path (Initiation Logic) tests are addressed in LC0 3.3.3. These tests are similar to the Matrix Logic tests, except that test power is withheld from one matrix relay at a time, allowing the initiation circuit to de- energize, opening the affected set of RTCBs. The RTCBs must then be closed prior to testing the other three initiation circuits, or a reactor trip may result.
Ehe Frequency of [92] days is based on the reliability analysis presented in topical report CEN-327, "RPSIESFAS Extended Test Interval CEOG STS B 3.3.1-30 Rev. 3.0, 03/31/04 RPS Instrumentation
-Operating (Analog)B 3.3.1 BASES SURVEILLANCE REQUIREMENTS (continued)
Bistable Tests The bistable setpoint must be found to trip within the Allowable Values specified in the LCO and left set consistent with the assumptions of the plant specific setpoint analysis (Ref.7).As found and as left values must also be recorded and reviewed for consistency with the assumptions of the frequency extension analysis.The requirements for this review are outlined in Reference 10.A test signal is superimposed on the input in one channel at a time to verify that the bistable trips within the specified tolerance around the setpoint.This is done with the affected RPS channel trip channel bypassed.Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint analysis.Matrix Logic Tests Matrix Logic tests are addressed in LCO 3.3.3.This test is performed one matrix at a time.It verifies that a coincidence in the two input channels for each Function removes power from the matrix relays.During testing, power is applied to the matrix relay test coils and prevents the matrix relay contacts from assuming their de-energized state.This test will detect any short circuits around the bistable contacts in the coincidence logic, such as may be caused by faulty bistable relay or trip channel bypass contacts.Trip Path Tests Trip Path (Initiation Logic)tests are addressed in LCO 3.3.3.These tests are similar to the Matrix Logic tests, except that test power is withheld from one matrix relay at a time, allowing the initiation circuit toenergize, opening the affected set of RTCBs.The RTCBs must then be closed prior to testing the other three initiation circuits, or a reactor trip may result.(lhe Frequency of[92]days is based on the reliability analysis presented in topical report CEN-327,"RPS/ESFAS Extended Test Interval Evaluation"(Ref.1 0).tt'...
-'\
...V'\5ert.Z)
CEOG STS B 3.3.1-30 Rev.3.0, 03/31/04 RPS Instrumentation - Operating (Analog)
B 3.3.1 BASES SURVEILLANCE REQUIREMENTS (continued) A CHANNEL CALIBRATION of the excore power range channels@*?
(~&nsures that the channels are reading accurately and within tolerance. The Surveillance verifies that the channel responds to a measured parameter within the necessary range and accuracy. CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drift between successive calibrations to ensure that the channel remains operational between successive tests. CHANNEL CALIBRATIONS must be performed consistent with the plant specific setpoint analysis.
The as found and as left values must also be recorded and reviewed for consistency with the assumptions of the frequency extension analysis. The requirements for this review are outlined in Reference
[lo]. A Note is added stating that the neutron detectors are excluded from CHANNEL CALIBRATION because they are passive devices with minimal drift and because of the difficulty of simulating a meaningful signal. Slow changes in detector sensitivity are compensated for by performing the daily calorimetric calibration (SR 3.3.1.2) and the monthly linear subchannel gain check (SR 3.3.1.3). In addition, associated control room indications are continuously monitored by the operators.
Ehe Frequency of 92 days is acceptable, based on plant operating experience, and takes into account indications and alarms available to the A CHANNEL FUNCTIONAL TEST on the Loss of Load and Power Rate of Change channels is performed prior to a reactor startup to ensure the entire channel will perform its intended function if required.
A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.
This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
The Loss of Load pressure sensor cannot be tested during reactor operation without closing the high pressure TSV, which would result in a turbine trip or reactor trip. The Power Rate of Change - High trip Function is required during startup operation and is bypassed when shut down or > 15% RTP. CEOG STS B 3.3.1-31 Rev. 3.0, 03/31/04 RPS Instrumentation
-Operating (Analog)B 3.3.1 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.1.5 A CHANNEL CALIBRATION of the excore power range that the channels are reading accurately and within tolerance.
The Surveillance verifies that the channel responds to a measured parameter within the necessary range and accuracy.CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drift between successive calibrations to ensure that the channel remains operational between successive tests.CHANNEL CALI BRA TIONS must be performed consistent with the plant specific setpoint analysis.The as found and as left values must also be recorded and reviewed for consistency with the assumptions of the frequency extension analysis.The requirements for this review are outlined in Reference[10].A Note is added stating that the neutron detectors are excluded from CHANNEL CALIBRATION because they are passive devices with minimal drift and because of the difficulty of simulating a meaningful signal.Slow changes in detector sensitivity are compensated for by performing the daily calorimetric calibration (SR 3.3.1.2)and the monthly linear subchannel gain check (SR 3.3.1.3).In addition, associated control room indications are continuously monitored by the operators.
Uhe Frequency of 92 days is acceptable, based on plant operating experience, and takes into account indications and alarms available to the operator in the control room.,(::..
,
SR 3.3.1.6 A CHANNEL FUNCTIONAL TEST on the Loss of Load and Power Rate of Change channels is performed prior to a reactor startup to ensure the entire channel will perform its intended function if required.A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
The Loss of Load pressure sensor cannot be tested during reactor operation without closing the high pressure TSV, which would result in a turbine trip or reactor trip.The Power Rate of Change-High trip Function is required during startup operation and is bypassed when shut down or>15%RTP.CEOG STS B 3.3.1-31 Rev.3.0, 03/31/04 RPS Instrumentation - Operating (Analog)
B 3.3.1 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.1.7 is a CHANNEL FUNCTIONAL TEST similar to SR 3.3.1.4, except SR 3.3.1.7 is applicable only to bypass Functions and is performed once within 92 days prior to each startup. A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions. Proper operation of bypass permissives is critical during plant startup because the bypasses must be in place to allow startup operation and must be removed at the appropriate points during power ascent to enable certain reactor trips. Consequently, the appropriate time to verify bypass removal function OPERABILITY is just prior to startup. The allowance to conduct this test within 92 days of startup is based on the reliability analysis presented in topical report CEN-327, "RPSIESFAS Extended Test Interval Evaluation" (Ref. 10). Once the operating bypasses are removed, the bypasses must not fail in such a way that the associated trip Function gets inadvertently bypassed. This feature is verified by the trip Function CHANNEL FUNCTIONAL TEST, SR 3.3.1.4. Therefore, further testing of the bypass function after startup is unnecessary.
SR 3.3.1.8 the performance of a CHANNEL CALIBRATION@ CHANNEL CALIBRATION is a complete check of the instrument channel including the sensor. The Surveillance verifies that the channel responds to a measured parameter within the necessary range and accuracy. CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drift between successive calibrations to ensure that the channel remains operational between successive tests. CHANNEL CALIBRATIONS must be performed consistent with the plant specific setpoint analysis.
The as found and as left values must also be recorded and reviewed for consistency with the assumptions of the frequency extension analysis.
The requirements for this review are outlined in Reference
[lo]. ice Frequency is based upon the assumption of an 18 month calibration Eu mterval for th; determination of the magnitude of equipment drift.
CEOG STS B 3.3.1-32 Rev. 3.0, 03/31/04 RPS Instrumentation
-Operating (Analog)B 3.3.1 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.1.7 SR 3.3.1.7 is a CHANNEL FUNCTIONAL TEST similar to SR 3.3.1.4, except SR 3.3.1.7 is applicable only to bypass Functions and is performed once within 92 days prior to each startup.A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
Proper operation of bypass permissives is critical during plant startup because the bypasses must be in place to allow startup operation and must be removedatthe appropriate points during power ascent to enable certain reactor trips.Consequently, the appropriate time to verify bypass removal function OPERABILITY is just prior to startup.The allowance to conduct thistestwithin 92 days of startup is based on the reliability analysis presented in topical report CEN-327,"RPS/ESFAS Extended Test Interval Evaluation" (Ref.10).Once the operating bypasses are removed, the bypasses must not fail in such a way that the associated trip Function gets inadvertently bypassed.This feature is verified by the trip Function CHANNEL FUNCTIONAL TEST, SR 3.3.1.4.Therefore, further testing of the bypass function after startup is unnecessary.
SR 3.3.1.8 3.1.8 is the performance of a CHANNEL CALIBRATION0 onth.CHANNEL CALIBRATION is a complete check of the instrument channel including the sensor.The Surveillance verifies that the channel responds to a measured parameter within the necessary range and accuracy.CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drift between successive calibrations to ensure that the channel remains operational between successive tests.CHANNEL CALIBRATIONS must be performed consistent with the plant specific setpoint analysis.The as found and as left values must also be recorded and reviewed for consistency with the assumptions of the frequency extension analysis.The requirements for this review are outlined in Reference[10].Ifhe Frequency is based upon the assumption of an 18 calibration Interval for the determination of the magnitude of equipment j)CEOG STS B Rev.3.0, 03/31/04 RPS Instrumentation - Operating (Analog)
B 3.3.1 BASES SURVEILLANCE REQUIREMENTS (continued) The Surveillance is modified by a Note to indicate that the neutron detectors are excluded from CHANNEL CALIBRATION because they are passive devices with minimal drift and because of the difficulty of simulating a meaningful signal.
Slow changes in detector sensitivity are compensated for by performing them calorimetric calibration (SR 3.3.1.2) and themlinear subchannel gain check (SR 3.3.1.3).
This SR ensures that the RPS RESPONSE TIMES are verified to be less than or equal to the maximum values assumed in the safety analysis. Individual component response times are not modeled in the analyses.
The analyses model the overall or total elapsed time from the point at which the parameter exceeds the trip setpoint value at the sensor to the point at which the RTCBs open. @esponse times are conducted on an [I81 month STAGGERED TEST BASIS.
This results in the interval between successive surveillances of a given channel of n x 18 months, where n is the number of channels in the function.
The Frequency of [I81 months is based upon operating experience, which has shown that random failures of instrumentation components causing serious response time degradation, but not channel failure, are infrequent occurrences.
Also, response times cannot be determined at power, since equipment operation is required.d~esting may be performed In one measurement or in overlapping segments, with verification that all components are tested.
-----+-----------------------------
REVIEWER'S NOTE ............................
(%~eTv7 .--------*-*-"" Applicable portions of the following TS Bases are applicable to plants adopting CEOG Topical Report CE NPSD-I 167-1, "Elimination of Pressure Sensor Response Time Testing Requirements." Response time may be verified by any series of sequential, overlapping or total channel measurements, including allocated sensor'response time, such that the response time is verified. Allocations for sensor response times may be obtained from records of test results, vendor test data, or vendor engineering specifications. Topical Report CE NPSD-1167-A, "Elimination of Pressure Sensor Response Time Testing Requirements," (Ref. 11) provides the basis and methodology for using allocated sensor response times in the overall verification of the channel response time for specific sensors identified in the Topical Report. Response time verification for other sensor types must be demonstrated by test.
The allocation of sensor response times must be verified prior to placing a new component in operation and reverified after maintenance that may adversely affect the sensor response time. CEOG STS Rev. 3.0, 03131104 RPS Instrumentation
-Operating (Analog)B 3.3.1 BASES SURVEILLANCE REQUIREMENTS (continued)
The Surveillance is modified by a Note to indicate that the neutron detectors are excluded from CHANNEL CALIBRATION because they arepassivedevices with minimal drift and because of the difficulty of simulating a meaningful signal.Slow changes in detector sensitivity are compensated for by Rerformingcalorimetric calibration (SR 3.3.1.2)and subchannel gain check (SR 3.3.1.3).SR 3.3.1.9 This SR ensures that the RPS RESPONSE TIMES are verified to be less than or equal to the maximum values assumed in the safety analysis.Individual component response times are not modeled in the analyses.The analyses model the overall or total elapsed time from the point at which the parameter exceeds the trip setpoint value at the sensor to the point at which the RTCBs open.(8esponse times are conducted on an[181 month STAGGERED TEST BASIS.This results in the interval between successive surveillances of a given channel ofnx 18 months, where n is the number of channels in the function.The Frequency of[181 months is based upon operating experience, which has shown that random failures of instrumentation components causing serious response time degradation, but not channel failure, are infrequent occurrences.
Also, response times cannot be determined at power, since equi men operation is required.Tes Ing may be pe orme In one measurement or in overlapping segments.with verification that all components are
,.:en..r-----------------------------------R EV I EWERS NOTE-------------------------------'
Applicable portions of the following TS Bases are applicable to plants adopting CEOG Topical Report CE NPSD-1167-1,"Elimination of Pressure Sensor Response Time Testing Requirements." Response time may be verified by any series of sequential, overlapping or total channel measurements, including allocated sensonesponse time, such that the response time is verified.Allocations for sensor response times may be obtained from records of test results.vendor test data, or vendor engineering specifications.
Topical Report CE NPSD-1167-A,"Elimination of Pressure Sensor Response Time Testing Requirements," (Ref.11)provides the basis and methodology for using allocated sensor response times in the overall verification of the channel response time for specific sensors identified in the Topical Report.Response time verification for other sensor types must be demonstrated by test.The allocation of sensor response limes must be verified prior to placing a new component in operation and reverified after maintenance that may adversely affect the sensor response time.CEOG STS B 3.3.1-33 Rev.3.0, 03/31/04 RPS Instrumentation - Shutdown (Analog)
B 3.3.2 BASES ACTIONS (continued) If Required Actions associated with these Conditions cannot be completed within the required Completion Time, opening the RTCBs brings the reactor to a MODE where the LC0 does not apply and ensures no CEA withdrawal will occur.
The basis for the Completion Time of 6 hours is that it is adequate to complete the Required Actions without challenging plant systems, including the insertion of CEAs for plants that normally maintain CEAs withdrawn when shut down. SURVEILLANCE
-----------------------------*
--- REVIEWER'S NOTE ..................................
REQUIREMENTS In order for a plant to take credit for topical reports as the basis for justifying Frequencies, topical reports must be supported by an NRC staff Safety Evaluation Report that establishes the acceptability of each topical report for that plant. Performance of the CHANNEL CHECK on each wide range channel- ~Mio~ensures that gross failure of instrumentation has not occurred.
A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on another channel. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the two instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more serious. CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying that the instrumentation continues to operate properly between each CHANNEL CALIBRATION. Agreement criteria are determined by the plant staff based on a combination of the channel instrument uncertainties, including isolation, indication, and readability.
If a channel is outside the criteria, it may be an indication that the transmitter or the signal processing equipment has drifted outside its limits.
Ehe Frequency, about once every shift, is based on operating experience that demonstrates the rarity of channel failure. Since the probability of two random failures in redundant channels in any 12 hour period is extremely low, the CHANNEL CHECK minimizes the chance of loss of protective function due to failure of redundant channels.
The CHANNEL CHECK supplements less formal, but more frequent, checks of channel OPERABILITY during normal operational use of the displays associated with the LC0 required channels. -e_vm CEOG STS B 3.3.2-7 Rev. 3.0, 03/31/04 RPS Instrumentation
-Shutdown (Analog)B 3.3.2 BASES ACTIONS (continued)
If Required Actions associated with these Conditions cannot be completed within the required Completion Time, opening the RTCBs brings the reactor to a MODE where the LCO does not apply and ensures no CEA withdrawal will occur.The basis for the Completion Time of 6 hours is that it is adequate to complete the Required Actions without challenging plant systems, including the insertion of CEAs for plants that normally maintain CEAs withdrawn when shut down.SURVEILLANCE REQUIREMENTS EVI EWE R'S NOTE w In order for a plant to take credit for topical reports as the basis for justifyingFrequencies,topical reports must be supported by an NRC staft Safety Evaluation Report that establishes the acceptability of each topical report for that plant.SR 3.3.2.1 Performance of the CHANNEL CHECK on each wide range that gross failure of instrumentation has not occurred.A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on another channel.It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value.Significant deviations between the two instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more serious.CHANNEL CHECK will detect gross channel failure;thus, it is key to verifying that the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
Agreement criteria are determined by the plant staft based on a combination of the channel instrument uncertainties, including isolation.
indication, and readability.
If a channel is outside the criteria, it may be an indication that the transmitter or the signal processing equipment has drifted outside its limits.[fhe Frequency, about once every shift, is based on operating experience that demonstrates the rarity of channel failure.Since the probability of two random failures in redundant channels in any 12 hour period is extremely low, the CHANNEL CHECK minimizes the chance of loss of protective function due to failure of redundant channels.The CHANNEL CHECK supplements less formal, but more frequent, checks of channel OPERABILITY during normal operational use of the displays associated with the LCO required channels.CEOGSTS B 3.3.2-7 Rev.3.0, 03/31/04 RPS Instrumentation - Shutdown (Analog)
B 3.3.2 BASES SURVEILLANCE REQUIREMENTS (continued)
A CHANNEL FUNCTIONAL TEST
-- on the power rate of change channels is performedfice
&en692 &bto ensure the entire channel will perform its intended function if reauired.
A successful test of the reauired contact(s) of a channel re'lay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions. The Power Rate of Change - High trip Function is required durin startup operation and is bypassed when shut down or
> 15% RTP. P Additionally, operating experience has shown that these components usually pass the Surveillance when performed at a Frequency of once every 92 days prior to each reactor startup. SR 3.3.2.3 is a CHANNEL FUNCTIONAL TEST similar to SR 3.3.2.2, except SR 3.3.2.3 is a~dicable onlv to bvaass Functions and is @rice @ithin 92paYg pri6r to eich startup. A successful test of the required coritact(s) of a channel relay may be performed by the verification of the cha&e of state of a single contact of the relay. This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions. Proper operation of bypass permissives is critical during plant startup because the bypasses must be in place to allow startup operation and must be removed at the appropriate points during power ascent to enable certain reactor trips. Consequently, the appropriate time to verify bypass removal function OPERABILITY is just prior to startup.
Ehe allowance to conduct this Surveillance within 92 days of startup is based on the reliability analysis presented in topical report CEN-327, "RPSIESFAS Extended Test Interval Evaluation" (Ref. 5) are removed, the bypasses must not fail in associated trip Function gets inadvertently bypassed. This feature is verified by the trip Function CHANNEL FUNCTIONAL TEST, SR 3.3.2.2. Therefore, further testing of the bypass function after startup is / unnecessary.
C?+*r-t 4 22 CEOG STS B 3.3.2-8 Rev. 3.0, 03/31/04 RPS Instrumentation
-Shutdown (Analog)B 3.3.2 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.2.2 A CHANNEL FUNCTIONAL TEST on the power rate of change channels is performed*fe ensure the entire channel will perform its intended function if required.A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
The Power Rate of Change-High trip Function is required startup operation and is bypassed when shut down or>15%RTP.LAdditionally, operating experience has shown that these components usually pass the Surveillance when performed at a Frequency of once every 92 days prior to each reactor startup.(i.Y\se;:{:2.]
SR 3.3.2.3 SR 3.3.2.3 is a CHANNEL FUNCTIONAL TEST similar to SR 3.3.2.2, except SR 3.3.2.3 is applicable only to bypass Functions and is performed nce ithVt9a prior to each startup.A successful test of the required contact(s of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
Proper operation of bypass permissives is critical during plant startup because the bypasses must be in place to allow startup operation and must be removed at the appropriate points during power ascent to enable certain reactor trips.Consequently, theappropriatetime to verify bypass removal function OPERABILITY is just prior to startup.Uhe allowance to conduct this Surveillance within 92 days of startup is based on the reliability analysis presented in topical report CEN-327,"RPS/ESFAS Extended Test Interval Evaluation" (Ref.5)nce Ing bypasses are removed, the bypasses must not fail in such a way that the associated trip Function gets inadvertently bypassed.This feature is verified by the trip Function CHANNEL FUNCTIONAL TEST, SR 3.3.2.2.Therefore, further testing of the bypass function after startup is unnecessary.
_CEOG STS B 3.3.2-8 Rev.3.0, 03/31/04 RPS Instrumentation - Shutdown (Analog)
B 3.3.2 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.2.4 is the performance of a CHANNEL CALIBRATION@
~~~- CHANNEL CALIBRATION is a complete check of the instrument channel including the sensor. The Surveillance verifies that the channel responds to a measured parameter within the necessary range and accuracy. CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drift between successive calibrations to ensure that the channel remains operational between successive tests. CHANNEL CALIBRATIONS must be performed consistent with the plant specific setpoint analysis. Only the Allowable Values are specified for each RPS trip Function. Nominal trip setpoints are specified in the plant specific setpoint calculations. The nominal setpoints are selected to ensure the setpoints measured by CHANNEL FUNCTIONAL TESTS do not exceed the Allowable Value if the bistable is performing as required. Operation with a trip setpoint less conservative than the nominal trip setpoint, but within its Allowable Value, is acceptable, provided that operation and testing are consistent with the assumptions of the plant specific setpoint calculations. Each Allowable Value specified is more conservative than the analytical limit assumed in the safety analysis in order to account for instrument uncertainties appropriate to the trip Function. These uncertainties are defined in the "Plant Protection System Selection of Trip Setpoint Values" (Ref. 4). The as found and as left values must also be recorded and reviewed for consistency with the assumptions of the surveillance interval extension analysis. The requirements for this review are outlined in Reference
: 5. Ghe Frequency is based upon the assumption of an [I81 month calibration interval in the determination of the magnitude of equipment drift.
6 The Surveillance is modified by a Note to indicate that the neutron (TED detectors are excluded from CHANNEL CALIBRATION because they are passive devices with minimal drift and because of the difficulty of simulating a meaningful signal. CEOG STS B 3.3.2-9 Rev. 3.0, 03/31/04 RPS Instrumentation
-Shutdown (Analog)B 3.3.2 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.2.4 SR 3.3.2.4 is the performance of a CHANNEL CALI BRA CHANNEL CALIBRATION is a complete check of the instrument channel including the sensor.The Surveillance verifies that the channel responds to a measured parameter within the necessary range and accuracy.CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drift between successive calibrations to ensure that the channel remains operational between successive tests.CHANNEL CALIBRATIONS must be performed consistent with the plant specific setpoint analysis.Only the Allowable Values are specified for each RPS trip Function.Nominal trip setpoints are specified in the plant specific setpoint calculations.
The nominal setpoints are selected to ensure the setpoints measured by CHANNEL FUNCTIONAL TESTS do not exceed the Allowable Value if the bistable is performing as required.Operation with a trip setpoint less conservative than the nominal trip setpoint, but within its Allowable Value, is acceptable, provided that operation and testing are consistent with the assumptions of the plant specific setpoint calculations.
Each Allowable Value specified is more conservative than the analytical limit assumed in the safety analysis in order to account for instrument uncertainties appropriate to the trip Function.These uncertainties are defined in the"Plant Protection System Selection of Trip Setpoint Values" (Ref.4).The as found and as left values must also be recorded and reviewed for consistency with the assumptions ofthesurveillance interval extension analysis.The requirements for this review are outlined in Reference 5.Uhe Frequency is based upon the assumption of an[18]month calibration interval in the determination of the magnitude of equipment drift.
The Surveillance is modified by a Note to indicate that the neutron detectors are excluded from CHANNEL CALIBRATION because they are passive devices with minimal drift and because of the difficulty of simulating a meaningful signal.CEOGSTS B 3.3.2-9 Rev.3.0, 03/31/04 RPS Logic and Trip lnitiation (Analog)
B 3.3.3 BASES ACTIONS (continued)
If two Manual Trip channels are inoperable and affecting the same trip leg, the associated RTCBs must be opened immediately to ensure Manual Trip capability is maintained. With the affected RTCBs open, any one of two Manual Trip push buttons being depressed will result in a reactor trip. If the affected RTCB(s) cannot be opened, Condition E is entered. This would only occur if there is a failure in the Manual Trip circuitry or the RTCB(s). E.l and E.2 Condition E is entered if Required Actions associated with Condition A, 6, or D are not met within the required Completion Time or if for one or more Functions more than one Manual Trip, Matrix Logic, lnitiation Logic, or RTCB channel is inoperable for reasons other than Condition A or D. If the RTCBs associated with the inoperable channel cannot be opened, the reactor must be shut down within 6 hours and all the RTCBs opened.
A Completion Time of 6 hours is reasonable, based on operating experience, to reach the required MODE from full power conditions in an orderly manner and without challenging plant systems and to open RTCBs. All RTCBs should then be opened, placing the plant in a MODE where the LC0 does not apply and ensuring no CEA withdrawal occurs.
UNCTIONAL TEST is performed on each RTCB channel This verifies proper operation of each RTCB. The RTCB must then be closed prior to testing the other RTCBs, or a reactor trip may result. Ehe Frequency of 31 days is based on the reliability analysis presented in Topical Report CEN-327, "RPSIESFAS Extended Test Interval ~valuat/on," (Ref. 5). MzL:;lFk-) CEOG STS 0 3.3.3-10 Rev. 3.0, 03/31/04 RPS Logic and Trip Initiation (Analog)B 3.3.3 BASES ACTIONS (continued)
If two Manual Trip channels are inoperable and affecting the same trip leg, the associated RTCBs must be opened immediately to ensure Manual Trip capability is maintained.
With the affected RTCBs open, any one of two Manual Trip push buttons being depressed will result in a reactor trip.If the affected RTCB(s)cannot be opened, Condition E is entered.This would only occur if there is a failure in the Manual Trip circuitry or the RTCB(s).E.1 and E.2 Condition E is entered if Required Actions associated with Condition A, B, or D are not met within the required Completion Time or if for one or more Functions more than one Manual Trip, Matrix Logic, Initiation Logic, or RTCB channel is inoperable for reasons other than Condition A or D.If the RTCBs associated with the inoperable channel cannot be opened, the reactor must be shut down within 6 hours and all the RTCBs opened.A Completion Time of 6 hours is reasonable, based on operating experience, to reach the required MODE from full power conditions in an orderly manner and without challenging plant systems and to open RTCBs.All RTCBs should then be opened, placing the plant in a MODE where the LCO does not apply and ensuring no CEA withdrawal occurs.SURVEILLANCE REQUIREMENTS
-----------------------------------REVI EWE R'S NOTE-----------------------------------
In order for a plant to take credit for topical reports as the basis for justifying Frequencies, topical reports must be supported by an NRC staff Safety Evaluation Report that establishes the acceptability of each topical report for that unit (Ref.4).SR 3.3.3.1 FUNCTIONAL TEST is performed on each RTCB channelZ1 This verifies proper operation of each RTCB.The RTCB must then be closed prior to testing the other RTCSs, or a reactor trip may result.fIDe Frequency of 31 days is based on the reliability analysis presented in Topical Report CEN-327,"RPS/ESFAS Extended Test Interval Evaluation," (Ref.5).4::
CEOG STS B 3.3.3-10 Rev.3.0, 03/31/04 RPS Logic and Trip Initiation (Analog) B 3.3.3 BASES SURVEILLANCE REQUIREMENTS (continued)
A CHANNEL FUNCTIO TEST on each RPS Logic channel is performed(everf[9%
d ensure the entire channel will perform its intended function when needed.
A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
In addition to power supply tests, the RPS CHANNEL FUNCTtONAL TEST consists of three overlapping tests as described in Reference
: 3. These tests verify that the RPS is capable of performing its intended function, from bistable input through the RTCBs. The first test, the bistable test, is addressed by SR 3.3.1.4 in LC0 3.3.1. This SR addresses the two tests associated with the RPS Logic: Matrix Logic and Trip Path. Matrix Loqic Tests These tests are performed one matrix at a time. They verify that a coincidence in the two input channels for each Function removes power from the matrix relays. During testing, power is applied to the matrix relay test coils and prevents the matrix relay contacts from assuming their de- energized state. The Matrix Logic tests will detect any short circuits around the bistable contacts in the coincidence logic such as may be caused by faulty bistable relay or trip channel bypass contacts. Trip Path Tests These tests are similar to the Matrix Logic tests, except that test power is withheld from one matrix relay at a time, allowing the initiation circuit to de-energize, opening the affected set of RTCBs. The RTCBs must then be closed prior to testing the other three initiation circuits, or a reactor trip may result. Ge Frequency of [92) days is based on the reliability analysis presented in topical report CEN-327, "RPSIESFAS Extended Test Interval Evaluation" (Ref. 5). d+.- (-..._ I CEOG STS B 3.3.3-1 1 Rev. 3.0, 03131104 RPS Logic and Trip Initiation (Analog)B 3.3.3 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.3.2 TEST on each RPS Logic channel is performed eve9d 0 ensure the entire channel will perform its intended function w en needed.A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
In addition to power supply tests, the RPS CHANNEL FUNCTIONAL TEST consists of threeoverlappingtests as described in Reference 3.These tests verify that the RPS is capable of performing its intended function, from bistable input through the RTCBs.The first test, the bistable test, is addressed by SR 3.3.1.4 in LCO 3.3.1.This SR addresses the two tests associated with the RPS Logic: Matrix Logic and Trip Path.Matrix Logic Tests These tests areperformedone matrix at a time.They verify that a coincidence in the two input channels for each Function removes power from the matrix relays.During testing, power is applied to the matrix relay test coils and prevents the matrix relay contacts from assuming theirenergized state.The Matrix Logic tests will detect any short circuits around the bistable contacts in the coincidence logic such as may be caused by faulty bistable relay or trip channel bypass contacts.Trip Path Tests These tests are similar to the Matrix Logic tests, except that test power is withheld from one matrix relay at a time, allowing the initiation circuit to de-energize, opening the affected set of RTCBs.The RTCBs must then be closed prior to testing the other three initiation circuits, or a reactor trip may result.(ihe Frequency of[92]days is based on the reliability analysis presented in topical report CEN-327,"RPS/ESFAS Extended Test Interval Evaluation" (Ref.5)."'"",e,"'.&----*,,--**--1"*
..-:'"""1.***
"\,.'("'0" ,d; CEOG STS B 3.3.3-11 Rev.3.0, 03/31/04 RPS Logic and Trip Initiation (Analog) B 3.3.3 BASES - -- - - .- - SURVEILLANCE REQUIREMENTS (continued)
A CHANNEL FUNCTIONAL TEST on the Manual Trip channels is performed prior to a reactor startup to ensure the entire channel will perform its intended function if required. A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions. The Manual Trip i Function can be tested either at power or shutdown. However, the simplicity of this circuitry and the absence of drift concern makes this Frequency adequate. Additionally, operating experience has shown that these components usually pass the Surveillance when performed once within 7 days prior to each reactor startup.
Each RTCB is actuated by an undervoltage coil and a shunt trip coil. The system is designed so that either de-energizing the undervoltage coil or energizing the shunt trip coil will cause the circuit breaker to open. When an RTCB is opened, either during an automatic reactor trip or by using the manual push buttons in the control room, the undervoltage coil is de- energized and the shunt trip coil is energized. This makes it impossible to determine if one of the coils or associated circuitry is defective.
Therefore, Gnce evkrv I 8/rn~~l1 a CHANNEL FUNCTIONAL TEST is performed that individually tests all four sets of undervoltage coils and all four sets of shunt trip coils. During undervoltage coil testing, the shunt trip coils shall remain de-energized, preventing their operation.
Conversely, during shunt trip coil testing, the undervoltage coils shall remain energized, preventing their operation. This Surveillance ensures that every undervoltage coil and every shunt trip coil is capable of performing its intended function and that no single active failure of any RTCB component will prevent a reactor trip.
A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical CEOG STS B 3.3.3-12 Rev. 3.0, 03131104 RPS Logic and Trip Initiation (Analog)B 3.3.3 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.3.3 A CHANNEL FUNCTIONAL TEST on the Manual Trip channels is performed prior to a reactor startup to ensure the entire channel will perform its intended function if required.A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
The Manual Trip Function can be tested either at power or shutdown.However, the simplicity of this circuitry and the absence of drift concern makes this Frequency adequate.Additionally, operating experience has shown that these components usually pass the Surveillance when performed once within 7 days prior to each reactor startup.[SR 3.3.3.4 Each RTCB is actuated by an undervoltage coil and a shunt trip coil.The system is designed so that either de-energizing the undervoltage coil or energizing the shunt trip coif will cause the circuit breaker to open.When an RTCB is opened.either during an automatic reactor trip or by using the manual push buttons in the control room, the undervoltage coil isenergized and the shunt trip coil is energized.
This makes it impossible to determine if one of the coils or associated circuitry is defective.
Therefore, lQrice' 18!fTlObi6])
a CHANNEL FUNCTIONAL TEST is performed that individually tests all four sets of undervoltage coils and all four sets of shunt trip coils.During undervoltage coil testing, the shunt trip coils shall remain de-energized, preventing their operation.
Conversely, during shunt trip coil testing, the undervoltagecoilsshall remain energized.
preventing their operation.
This Surveillance ensures that every undervoltage coil and every shunt trip coil is capable of performing its intended function and that no single active failure of any RTCB component will prevent a reactor trip.A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical CEOG STS B 3.3.3-12 Rev.3.0, 03/31/04 RPS Logic and Trip lnitiation (Analog)
B 3.3.3 BASES SURVEILLANCE REQUIREMENTS (continued) Specifications tests at least once per refueling interval with applicable extensions.
ahe 18 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power. Operating experience has shown these components usually pass the Surveillance when performed at the Frequency of once every 18 months.
+- 55ex3 If one set of RTCBs has been opened in response to a single RTCB channel, lnitiation Logic channel, or Manual Trip channel failure, the affected set of RTCBs may be closed for up to 1 hour for Surveillance on the OPERABLE Initiation Logic, RTCB, and Manual Trip channels.
In this case, the redundant set of RTCBs will provide protection if a trip should be required. It is unlikely that a trip will be required during the Surveillance, coincident with a failure of the remaining series RTCB channel. If a single matrix power supply or vital bus failure has opened two sets of RTCBs, Manual Trip and RTCB testing on the closed breakers cannot be performed without causing a trip.
] REFERENCES
: 1. 10 CFR 50, Appendix A. 2. 10 CFR 100. 3. FSAR, Section
[7.2]. 4. NRC Safety Evaluation Report, [Date]. 5. CEN-327, June 2, 1986, including Supplement 1, March 3, 1989. CEOG STS Rev. 3.0, 03/31/04 RPS Logic and Trip Initiation (Analog)B 3.3.3 BASES SURVEILLANCE REQUIREMENTS (continued)
Specifications tests at least once per refueling interval with applicable extensions.
Uhe 18 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power.Operating experience has shown these components usually pass the Surveillance when performed at the Frequency of once every 18 months.
If one set of RTCBs has been opened in response to a single RTCB channel, Initiation Logic channel, or Manual Trip channel failure, the affected set of RTCBs may be closed for up to 1 hour for Surveillance on the OPERABLE Initiation Logic, RTCB, and Manual Trip channels.In this case, the redundant set of RTCBs will prOVide protection if a trip should be required.It is unlikely that a trip will be required during the Surveillance, coincident with a failure of the remaining series RTCB channel.If a single matrix power supply or vital bus failure has opened two sets of RTCBs, Manual Trip and RTCB testing on the closed breakers cannot be performed without causing a trip.]REFERENCES 1.10 CFR 50, Appendix A.2.10 CFR 100.3.FSAR, Section[7.2].4.NRC Safety EvaluationReport,[Date].
5.CEN-327, June 2, 1986, including Supplement 1, March 3, 1989.CEOG STS B 3.3.3-13 Rev.3.0, 03/31/04 i ESFAS Instrumentation (Analog)
B 3.3.4 BASES ACTIONS (continued)
F.l and F.2 If the Required Actions and associated Completion Times of Condition A, B, C, D, or E are not met, the plant must be brought to a MODE in which the LC0 does not apply. To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 4 within
[I21 hours. The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems. SURVEILLANCE The SRs for any particular ESFAS Function are found in the SRs column REQUIREMENTS of Table 3.3.4-1 for that Function.
Most functions are subject to CHANNEL CHECK, CHANNEL FUNCTIONAL TEST, CHANNEL CALIBRATION, and response time testing. -.--*r.ru-----.. Performance of the CHANNEL  CHECK*^ e-o$ensures that a aross failure of instrumentation has not occurred. A CHANNEL CHECK is iormally a comparison of the parameter indicated on one channel to a similar parameter on other channels. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more serious. CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION. Agreement criteria are determined by the plant staff based on a combination of the channel instrument uncertainties, including indication and readability.
If a channel is outside the criteria, it may be an indication that the sensor or the signal processing equipment has drifted outside its limit. If the channels are within the criteria, it is an indication that the channels are OPERABLE. If the channels are normally off scale during CEOG STS B 3.3.4-18 Rev. 3.0, 03/31/04 ESFAS Instrumentation (Analog)B 3.3.4 BASES ACTIONS (continued)
F.1 and F.2 If the Required Actions and associated Completion Times of Condition A, B, C, D, or E are not met, the plant must be brought to a MODE in which the LCO does not apply.To achieve this status, the plant must be brought to at least MODE 3 within 6 hours and to MODE 4 within[12]hours.The allowed Completion Times are reasonable, based on operating experience, to reach the required plant conditions from full power conditions in an orderly manner and without challenging plant systems.SURVEILLANCE REQUIREMENTS The SRs for any particular ESFAS Function are found in the SRs column of Table 3.3.4*1 for that Function.Most functions are subject to CHANNEL CHECK, CHANNEL FUNCTIONAL TEST, CHANNEL CALIBRATION, and response time testing.
I EWE R'S NOTE In order for a unit to take credit for topical reports as the basis for justifying Frequencies, topical reports should be supported by an NRC staff Safety Evaluation Report that establishes the acceptability of each topical report for that unit.SR 3.3.4.1 Performance of the CHANNEL that a gross failure of instrumentation has not occurred.A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels.It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value.Significant deviations between instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more serious.CHANNEL CHECK will detect gross channel failure;thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
Agreement criteria are determined by the plant staff based on a combination of the channel instrument uncertainties, inclUding indication and readability.
If a channel is outside the criteria, it may be an indication that the sensor or the signal processing equipment has drifted outside its limit.If the channels are within the criteria, it is an indication that the channels are OPERABLE.If the channels are normally off scale during CEOG STS B 3.3.4-18 Rev.3.0, 03/31/04 ESFAS Instrumentation (Analog)
B 3.3.4 BASES SURVEILLANCE REQUIREMENTS (continued) times when Surveillance is required, the CHANNEL CHECK will only verify that they are off scale in the same direction.
Offscale low current loop channels are verified to be reading at the bottom of the range and not failed downscale.
chi Frequency of about once every shift is based on operating experience that demonstrates channel failure is rare. Since the probability of two random failures in redundant channels in any 12 hour period is extremely low, the CHANNEL CHECK minimizes the chance of loss of protective function due to failure of redundant channels.
The CHANNEL CHECK supplements less formal, but more frequent, checks of CHANNEL OPERABILITY during normal operational use of displays associated with the LC0 required channels.
C., 0 CHANNEL FUNCTIONAL TEST is performed every
[92] days to ensure the entire channel will perform its intended function when needed4A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.
This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
The CHANNEL FUNCTIONAL TEST tests the individual sensor subsystems using an analog test input to each bistable.
A test signal is superimposed on the input in one channel at a time to verify that the bistable trips within the specified tolerance around the setpoint.
Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint analysis.
The as found and as left values must also be recorded and reviewed for consistency with the assumptions of the surveillance interval extension analysis.
The requirements for this review are outlined in Reference
[8]. CEOG STS B 3.3.4-19 Rev. 3.0, 03/31/04 ESFAS Instrumentation (Analog)B 3.3.4 BASES SURVEILLANCE REQUIREMENTS (continued) timeswhenSurveillance is required, the CHANNEL CHECK will only verify that they are off scale in the same direction.
Offscale low current loop channels are verified to be reading at the bottom of the range and not failed downscale.(Jhe Frequency of about once every shift is based on operating experience that demonstrates channel failure is rare.Since the probability of two random failures in redundant channels in any 12 hour period is extremely low, the CHANNEL CHECK minimizes the chance of loss of protective function due to failure of redundant channels.The CHANNEL CHECK supplements less formal, but more frequent, checks of CHANNEL OPERABILITY during normal operational use of displays associated with the LCO required channels.
__
SR 3.3.4.2[A CHANNEL FUNCTIONAL TEST is performed every[92]days to ensure the entire channel will perform its intended function when-se;--,:n:
successful test of the required contact(s) of a channel relay may be.J:..I.J performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
The CHANNEL FUNCTIONAL TEST tests the individual sensor subsystems using an analog test input to each bistable.A test signal is superimposed on the input in one channel at a time to verify that the bistable trips within the specified tolerance around the setpoint.Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint analysis.The as found and as left values must also be recorded and reviewed for consistency with the assumptions of the surveillance interval extension analysis.The requirements for this review are outlined in Reference[8].CEOG STS B 3.3.4-19 Rev.3.0, 03/31/04 ESFAS Instrumentation (Analog)
B 3.3.4 BASES SURVEILLANCE REQUIREMENTS (continued)
C bhe Frequency is based upon the assumption of an [I81 month calibration interval for the determination of the magnitude of equipment drift in the setpoint analysis.
f-% This Surveillance ensures that the train actuation response times are the maximum values assumed in the safety analyses. Individual component response times are not modeled in the analyses. The analysis models the overall or total elapsed time, from the point at which the parameter exceeds the trip setpoint value at the sensor to the point at which the equipment in both trains reaches the required functional state (e.g., pumps at rated discharge pressure, valves in full open or closed position). Response time testing acceptance criteria are included in Reference
: 3. The test may be performed in one measurement or in overlapping segments, with verification that all components are measured.
------------------------+----------
REVIEWER'S NOTE ................................... Applicable portions of the following TS Bases are applicable to plants adopting CEOG Topical Report CE NPSD-1167-1, "Elimination of Pressure Sensor Response Time Testing Requirements." Response time may be verified by any series of sequential, overlapping or total channel measurements, including allocated sensor response time, such that the response time is verified. Allocations for sensor response times may be obtained from records of test results, vendor test data, or vendor engineering specifications. Topical Report CE NPSD-1167-A, "Elimination of Pressure Sensor Response Time Testing Requirements," (Ref. 10) provides the basis and methodology for using allocated sensor response times in the overall verification of the channel response time for specific sensors identified in the Topical Report. Response time verification for other sensor types must be demonstrated by test. The allocation of sensor response times must be verified prior to placing a new component in operation and reverified after maintenance that may adversely affect the sensor response time. CEOG STS B 3.3.4-21 Rev. 3.0, 03/31/04 ESFAS Instrumentation (Analog)B 3.3.4 BASES SURVEILLANCE REQUIREMENTS (continued)
Ghe Frequency is based upon the assumption of an[18]month calibration interval for the determination of the magnitude of equipment drift in the setpoint analysis.SR 3.3.4.5 This Surveillance ensures that the train actuation response times are the maximum values assumed in the safety analyses.Individual component response times are not modeled in the analyses.The analysis models the overall or total elapsed time, from the point at which the parameter exceeds the trip setpoint value at the sensor to the point at which the equipment in bothtrainsreaches the required functional state (e.g., pumps at rated discharge pressure, valves in full open or closed position).
Response time testing acceptance criteria are included in Reference 3.The test may be performed in one measurement or in overlapping segments, with verification that all components are measured.-----------------------------------REV I EWE R'S NOTE Applicable portions of the following TS Bases are applicable to plants adopting CEOG Topical Report CE NPSD-1167-1,"Elimination of Pressure Sensor Response Time Testing Requirements." Response time may be verified by any series of sequential, overlapping or total channel measurements, including allocated sensor response time, such that the response time is verified.Allocations for sensor response times may be obtained from records of test results, vendor test data, or vendor engineering specifications.
Topical Report CE NPSD-1167-A,"Elimination of Pressure Sensor Response Time Testing Requirements," (Ref.10)provides the basis and methodology for using allocated sensor response times in the overall verification of the channel response time for specific sensors identified in the Topical Report.Response time verification for other sensor types must be demonstrated by test.The allocation of sensor response times must be verified prior to placing a new component in operation and reverified after maintenance that may adversely affect the sensor response time.CEOG STS Rev.3.0, 03/31/04 ESFAS Instrumentation (Analog)
B 3.3.4 BASES SURVEILLANCE REQUIREMENTS (continued)
~ESF RESPONSE TIME tests are conducted on a STAGGERED TEST BASIS of once every
[I81 months. This results in the interval between successive tests of a given channel of n x 18 months, where n is the number of channels in the Function. Surveillance of the final actuation devices, which make up the bulk of the response time, is included in the testing of each channel. Therefore, staggered testing results in response time verification of these devices every
[18] months. The 1181 month STAGGERED TEST BASIS Frequency is based upon plant operating experience, which shows that random failures of instrumentation components causing serious response time dation, but not channel failure, are infrequent occurrences.
C~n~~~ -3 ., REFERENCES 1.
: 2. 3. 4. 5. 6. 7. 8. 9. 10. FSAR, Section [7.3]. 10 CFR 50, Appendix A. NRC Safety Evaluation Report, [Date]. IEEE Standard 279-1971. FSAR, Chapter
[14]. 10 CFR 50.49. "Plant Protection System Selection of Trip Setpoint Values." FSAR, Section [7.2]. CEN-327, June 2, 1986, including Supplement 1, March 3, 1989.
CEOG Topical Report CE NPSD-1167-A, "Elimination of Pressure Sensor Response Time Testinn Reauirements." CEOG STS Rev. 3.0, 03/31/04 ESFAS Instrumentation (Analog)B 3.3.4 BASES SURVEILLANCE REQUIREMENTS (continued)
[ESF RESPONSE TIME tests are conducted on a STAGGERED TEST BASIS of once every[18J months.This results in the interval between successive tests of a given channel ofnx 18 months, where n is the number of channels in the Function.Surveillance of the final actuation devices, which make up the bulk of the response time, is included in the testing of each channel.Therefore, staggered testing results in response time verification of these devices every[18J months.The[18]month STAGGERED TEST BASIS Frequency is based UPOrl plant operating experience, which shows that random failures of instrumentation components causing serious response time de radation, but not channel failure, are infrequent occurrences.
k''''''''"""", I:\:::\'&sect;,'e::.;;:"e'''i:, REFERENCES 1.FSAR, Section[7.3].2.10 CFR 50, Appendix A.3.NRC Safety Evaluation Report,[Date].4.IEEE Standard 279-1971.5.FSAR, Chapter[14].6.10 CFR 50.49.7."Plant Protection System Selection of TripSetpointValues." 8.FSAR, Section[7.2].9.CEN-327, June 2,1986, including Supplement 1, March 3,1989.10.CEOG Topical Report CE NPSD-1167-A,"Elimination of Pressure Sensor Response Time Testing Requirements." CEOG STS Rev.3.0, 03/31/04 ESFAS Logic and Manual Trip (Analog)
B 3.3.5 BASES SURVEILLANCE SR 3.3.5.1 REQUIREMENTS A CHANNEL FUNCTIONAL TEST is performed the entire channel will perform its intended Sensor subsystem tesis are addressed in LC0 3.3.4. This SR addresses Actuation Logic tests. A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay.
This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
Actuation Loaic Tests Actuation subsystem testing includes injecting one trip signal into each two-out-of-four logic subsystem in each ESFAS Function and using a bistable trip input to satisfy the trip logic.
Initiation relays associated with the affected channel will then actuate the individual ESFAS components. Since each ESFAS Function employs subchannels of Actuation Logic, it is possible to actuate individual components without actuating an entire ESFAS Function.
Note 1 requires that Actuation Logic tests include operation of initiation relays. Note 2 allows deferred at power testing of certain relays to allow for the fact that operating certain relays during power operation could cause plant transients or equipment damage. Those initiation relays that cannot be tested at power must be tested in accordance with Note
: 2. These include [SIAS No. 5, SIAS No. 10, ClAS No. 5, and MSlS No. 1 .] These relays actuate the following components, which cannot be tested at power:
RCP seal bleedoff isolation valves, 0 Service water isolation valves, VCT discharge valves, Letdown stop valves, CCW to and from the RCPs, MSlVs and feedwater isolation valves, and Instrument air containment isolation valves. CEOG STS B 3.3.5-12 Rev. 3.0, 03/31/04 ESFAS Logic and Manual Trip (Analog)B 3.3.5 BASES SURVEILLANCE SR 3.3.5.1 REQUIREMENTS A CHANNEL FUNCTIONAL TEST is ensure the entire channel will perform its intended function when needed.Sensor subsystem tests are addressed in LCO 3.3.4.This SR addresses Actuation Logic tests.A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
Actuation Logic Tests Actuation subsystem testing includes injecting one trip signal into each two-out-of-four logic subsystem in each ESFAS Function and using a bistable trip input to satisfy the triplogic.Initiation relays associated with the affected channel will then actuate the individual ESFAS components.
Since each ESFAS Function employs subchannels of Actuation Logic, it is possible to actuate individual components without actuating an entire ESFAS Function.Note 1 requires that Actuation Logic tests include operation of initiation relays.Note 2 allows deferred at power testing of certain relays to allow for the fact that operating certain relays during power operation could cause plant transients or equipment damage.Those initiation relays that cannot be tested at power must be tested in accordance with Note 2.These include[SIAS No.5, SIAS NO.1 0, CIAS No.5, and MSIS No.1.]These relays actuate the following components, which cannot be tested at power:*RCP seal bleedoff isolation valves,*Service water isolation valves,*VCT discharge valves,*Letdown stop valves,*CCW to and from the RCPs,*MSIVs and feedwater isolation valves, and*Instrument air containment isolation valves.CEOG STS B 3.3.5-12 Rev.3.0, 03/31/04 ESFAS Logic and Manual Trip (Analog)
B 3.3.5 BASES SURVEILLANCE REQUIREMENTS (continued)
The reasons that each of the above cannot be fully tested at power are stated in Reference I. These tests verify that the ESFAS is capable of performing its intended function, from bistable input through the actuated components.
Ehe Frequency of [92] days is based on the reliability analysis presented in topical report CEN-327, "RPSIESFAS Extended Test Interval Evaluation" (Ref.
2). 4--+- -.N--".- .- A CHANNEL FUNCTIONAL TEST is performed on the manual ESFAS actuation circuitry, de-energizing relays and providing Manual Trip of the Function. A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions. This Surveillance verifies that the trip push buttons are capable of opening contacts in the Actuation Logic as designed, de-energizing the initiation relays and providing Manual Trip of the Function.
Ehe [18] month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power. Operating experience has shown these components usually pass the Surveillance w requency of once every [18] months. REFERENCES
: 1. FSAR, Section [7.3]. 2. CEN-327, June
: 2. 1986, includincl Su~~lement
: 1. March 3, 1989. CEOG STS Rev. 3.0, 03/31/04 ESFAS logic and Manual Trip (Analog)B 3.3.5 BASES SURVEILLANCE REQUIREMENTS (continued)
The reasons that each of the above cannot be fully tested at power are stated in Reference 1.These tests verify that the ESFAS is capable of performing its intended function, from bistable input through the actuated components.
[he Frequency of[92]days is based on the reliability analysis presented in topical report CEN-327,"RPS/ESFAS Extended Test Interval Evaluation" (Ref.2).(--_..'...............
SR 3.3.5.2 A CHANNEL FUNCTIONAL TEST is performed on the manual ESFAS actuation circuitry, de-energizing relays and providing Manual Trip of the Function.A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
This Surveillance verifies that the trip push buttons are capable of opening contacts in the Actuation Logic as designed, de-energizing the i':litiation relays and providing Manual Trip of the Function.u:'he[18]month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power.Operating experience has shown these components usually pass the Surveillance Frequency of once every[18]months.:(r......--, S e.r t 2.)REFERENCES 1.FSAR, Section[7.3].2.CEN-327, June 2,1986, including Supplement 1, March 3,1989.\CEOG STS B 3.3.5-13 Rev.3.0, 03/31/04 DG - LOVS (Analog)
B 3.3.6 BASES ACTIONS (continued) Condition C applies when more than two undervoltage or Degraded Voltage channels on a single bus are inoperable. Required Action C.1 requires all but two channels to be restored to OPERABLE status within 1 hour. With more than two channels inoperable, the logic is not capable of providing a DG - LOVS signal for valid Loss of Voltage or Degraded Voltage conditions. The 1 hour Completion Time is reasonable to evaluate and take action to correct the degraded condition in an orderly manner and takes into account the low probability of an event requiring LOVS occurring during this interval.
Condition D applies if the Required Actions and associated Completion Times are not met. Required Action D. 1 ensures that Required Actions for the affected DG inoperabilities are initiated. Depending upon plant MODE, the actions specified in LC0 3.8.1, "AC Sources - Operating," or LC0 3.8.2 are required immediately.
SURVEILLANCE The following SRs apply to each DG - LOVS Function.
REQUIREMENTS
[SR 3.3.6.1 Performance of the CHANNEL CHECK~~V&~ -ensures that W' ' a gross failure of instrumentation has not occurred.
A CHANNEL CHECK is normally a comparison of the indicated output of the potential transformers that feed the LOVS undervoltage relays. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the two channels could be an indication of excessive drift in one of the channels or of something even more serious. CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying that the instrumentation continues to operate properly between each CHANNEL CALIBRATION. CEOG STS B 3.3.6-6 Rev. 3.0, 03/31/04 DG-LOVS (Analog)B 3.3.6 BASES ACTIONS (continued)
Condition C applies when more than two undervoltage or Degraded Voltage channels on a single bus are inoperable.
Required Action C.1 requires all but two channels to be restored to OPERABLE status within 1 hour.With more than two channels inoperable, the logic is not capable of providing a DG-LOVS signal for valid Loss of Voltage or Degraded Voltage conditions.
The 1 hour Completion Time is reasonable to evaluate and take action to correct the degraded condition in an orderly manner and takes into account the low probability of an event requiring LOVS occurring during this interval.Condition D applies if the Required Actions and associated Completion Times are not met.Required Action D.1 ensures that Required Actions for the affected DG inoperabilities are initiated.
Depending upon plant MODE, the actions specified in LCO 3.8.1,"AC Sources-Operating," or LCO 3.8.2 are required immediately.
SURVEILLANCE REQUIREMENTS The following SRs apply to each DG-LOVS Function.[SR 3.3.6.1 Performance of the CHANNEL that a gross failure of instrumentation has not occurred.A CHANNEL CHECK is normally a comparison of the indicated output of the potential transformers that feed the LOVS undervoltage relays.It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value.Significant deviations between the two channels could be an indication of excessive drift in one of the channels or of somethingevenmore serious.CHANNEL CHECK will detect gross channel failure;thus, it is key to verifying that the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
CEOG STS B 3.3.6-6 Rev.3.0, 03/31/04 DG - LOVS (Analog)
B 3.3.6 BASES SURVEILLANCE REQUIREMENTS (continued) Agreement criteria are determined by the plant staff, based on a combination of the channel instrument uncertainties, including indication and readability. If the channels are within the criteria, it is an indication that the channels are OPERABLE.
] [ The Frequency, about once every shift, is based upon operating experience that demonstrates channel failure is rare. Since the probability of two random failures in redundant channels in any 12 hour period is extremely low, the CHANNEL CHECK minimizes the chance of loss of protective function due to failure of redundant channels.
The CHANNEL CHECK supplements less formal, but more frequent, checks of channel OPERABILITY during normal o associated with the LC0 required channels A CHANNEL FUNCTIONAL TEST is performedgvd92,,J&ay$o ensure that the entire channel will perform its intended function when needed. A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
Ehe Frequency of
[92] days is based on plant operating experience with regard to channel OPERABILITY and drift, which demonstrates that failure of more than one channel of a given function in any [92] day Frequency is a rare event. Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint analysis.
The as found and as left values must also be recorded and reviewed for consistency with the assumptions of the surveillance interval extension analysis.
The requirements for this review are outlined in Reference
[6]. CEOG STS B 3.3.6-7 Rev. 3.0, 03/31/04 DG-LOVS (Analog)B 3.3.6 BASES SURVEILLANCE REQUIREMENTS (continued)
Agreement criteria are determined by the plant staff, based on a combination of the channel instrument uncertainties, including indication and readability.
If the channels are within the criteria, it is an indication that the channels are OPERABLE.][The Frequency, about once every shift, is based upon operating experience that demonstrates channel failure is rare.Since the probability of two random failures in redundant channels in any 12 hour period is extremely low, the CHANNEL CHECK minimizes the chance of loss of protective function due to failure of redundant channels.The CHANNELCHECKsupplements less formal, but more frequent, checks of channel OPERABILITY during normal operational use of the displays associated with the LCO required
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SR 3.3.6.2 A CHANNEL FUNCTIONAL TEST is performed ensure that the entire channel will perform its intended function when needed.A successful test of the required contact{s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
I!he Frequency of[92]days is based on plant operating experience with regard to channel OPERABILITY and drift, which demonstrates that failure of more than one channel of a given function in any[92]day Frequency is a rare event.Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint analysis.
The as found and as left values must also be recorded and reviewed for consistency with the assumptions of the surveillance interval extension analysis.The requirements for this review are outlined in Reference[6].CEOG STS Rev.3.0, 03/31/04 DG - LOVS (Analog)
B 3.3.6 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.6.3 is the performance of a CHANNEL CALIBMTION~
@=$. The CHANNEL CALIBRATION verifies the accuracy of each component within the instrument channel. This includes calibration of the undervoltage relays and demonstrates that the equipment falls within the specified operating characteristics defined by the manufacturer. The Surveillance verifies that the channel responds to a measured parameter within the necessary range and accuracy.
CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drift between successive calibrations to ensure that the channel remains operational between successive tests. CHANNEL CALIBRATIONS must be performed consistent with the plant specific setpoint analysis. The as found and as left values must also be recorded and reviewed for consistency with the assumptions of the surveillance interval extension analysis.
The requirements for this review are outlined in Reference
[6]. The setpoints, as well as the response to a Loss of Voltage and Degraded Voltage test, shall include a single point verification th t the trip occurs within the required delay time as shown in Reference
: 1. f The Frequency is based upon the assumption of an [I81 month calibration interval for the determination of the magnitude of equipment drift in the .-nur* LVCI*u'...t",*W setpoint analysis.
+-+--.. *Iw -T n 22 REFERENCES I. FSAR, 'Section [8.3]. 2. FSAR, Chapter 1151. 3. "Plant Protection System Selection of Trip Setpoint Values." 4. IEEE Standard 279-1971
: 5. 10 CFR 50, Appendix A, GDC 21. CEOG STS Rev. 3.0, 03/31/04 DG-LOVS (Analog)B 3.3.6 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.6.3 SR 3.3.6.3 is the performance of a CHANNEL CALIBRATION@)
The CHANNEL CALIBRATION verifies the accuracy of each component within the instrument channel.This includes calibration of the undervoltage relays and demonstrates that the equipment falls within the specified operating characteristics defined by the manufacturer.
The Surveillance verifies that the channel responds to a measured parameter within the necessary range and accuracy.CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drift between successive calibrations to ensure that the channel remains operational between successive tests.CHANNEL CALIBRATIONS must be performed consistent with the plant specific setpoint analysis.The as found and as left values must also be recorded and reviewed for consistency with the assumptions of the surveillance interval extension analysis.The requirements for this review are outlined in Reference[6].The setpoints, as well as the response to a Loss of Voltage and Degraded Voltage test, shall include a single point verification the trip occurs within the required delay time as shown in Reference 1.l.Ihe Frequency is based upon the assumption of an[18]month calibration interval for the determination of the magnitude of equipment drift in the setpoint analysis...........".*2;LfD REFERENCES 1.FSAR, Section[8.3].2.FSAR, Chapter[15].3."Plant Protection System Selection of Trip Setpoint Values." 4.IEEE Standard 279-1971.5.10 CFR 50, Appendix A, GDC 21.6.[]CEOG STS B 3.3.6-8 Rev.3.0, 03/31/04 CPlS (Analog) B 3.3.7 BASES ACTIONS (continued) instrumentation of the CPlS LCO. The Required Action directs the operator to take actions that are appropriate for the containment isolation Function of the CPlS without initiating the containment air supply and exhaust fans.
The Completion Time accounts for the fact that the automatic capability to isolate containment and initiate supply and exhaust fans on valid containment high radiation signals is degraded during conditions in which a fuel handling accident is possible and CPlS provides the only automatic mitigation of radiation release.
SURVEILLANCE SR 3.3.7.1 REQUIREMENTS Performance of the CHANNEL CHECK~C#~~V l~u~ensures that a gross failure of instrumentation has not occurred.
A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels.
It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the two instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more serious. CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION. Agreement criteria are determined by the plant staff, based on a combination of the channel instrument uncertainties, including indication and readability. If a channel is outside the criteria, it may be an indication that the transmitter or the signal processing equipment has drifted outside its limits. Ehe Frequency, about once every shift, is based on operating experience that demonstrates the rarity of channel failure. Since the probability of two random failures in redundant channels in any 12 hour period is low, the CHANNEL CHECK minimizes the chance of loss of protective function due to failure of redundant channels. The CHANNEL CHECK supplements less formal, but more frequent, checks of channel OPERABILITY during normal operational use of the displays associated with the LC0 required channels.
QYA <.* ."W* "-m *v ,",," w*fm ;,""w, v\se. A) u.*C"cc.r.ciur^.i " " CEOG STS - . -. - Rev. 3.0, 03/31/04 CPIS (Analog)B 3.3.7 BASES ACTIONS (continued) instrumentation of the CPIS LCO.The Required Action directs the operator to take actions that are appropriate for the containment isolation Function of the CPIS without initiating the containment air supply and exhaust fans.The Completion Time accounts for the fact that the automatic capability to isolate containment and initiate supply and exhaust fans on valid containment high radiation signals is degraded during conditions in which a fuel handling accident is possible and CPIS provides the only automatic mitigation ofradiationrelease.
SURVEILLANCE REQUIREMENTS SR 3.3.7.1 Performance of the CHANNEL CHECK 1
that a gross failure of instrumentation has not occurred.A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels.It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value.Significant deviations between the two instrument channels could be an indication of excessive instrument drift in one of the channels or of somethingevenmore serious.CHANNEL CHECK will detect gross channel failure;thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
Agreement criteria are determined by the plant staff, based on a combination of the channel instrument uncertainties, including indication and readability.
If a channel is outside the criteria, it may be an indication that the transmitter or the signal processing equipment has drifted outside its limits.Ghe Frequency, about once every shift, is based on operating experience that demonstrates the rarity of channel failure.Since the probability of two random failures in redundant channels in any 12 hour period is low, the CHANNEL CHECK minimizes the chance of loss of protective function due to failure of redundant channels.The CHANNEL CHECK supplements less formal, but more frequent, checks of channel OPERABILITY during normal operational use of the displays associated with the LCD required
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....CEOG STS B 3.3.7-5 Rev.3.0, 03/31/04 CPlS (Analog) B 3.3.7 BASES SURVEILLANCE REQUIREMENTS (continued) A CHANNEL FUNCTIONAL TEST is performed on each containment radiation monitoring channel to ensure the entire channel will perform its intended function. A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint analysis.
Ee Frequency of [92] days is based on plant operating experience with renard to channel OPERABILITY and drift, which demonstrates that failure of more than one channel 7v,*.d~-~+M of a %en "--+.-, Function in any [92] day interval is a rare event.
4J cr*. ?-q~ _t~&) Proper operation of the initiation relays is verified by de-energizing these rela s_durin the CHANNEL FUNCTIONAL TEST of the Actuation Logic ev This will actuate the Function, operating all associated equipment. Proper operation of the equipment actuated by each train is thus verified. A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions. A Note indicates this Surveillance includes verification of operation for each initiation relay.
Ge Frequency of [31] days is based on plant operating experience with regard to channel OPERABILITY, which demonstrates that failure of more than one channel of a given Function in any 1311 day interval is a rare CEOG STS B 3.3.7-6 Rev. 3.0, 03/31/04 CPIS (Analog)B 3.3.7 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.7.2 A CHANNEL FUNCTIONAL TEST is performed on each containment radiation monitoring channel to ensure the entire channel will perform its intended function.A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint analysis.[he Frequency of[92]days is based on plant operating experience with regard to channel OPERABILITY and drift, which demonstrates that failure of more than one in any[92]day interval is a rare event.
SR 3.3.7.3 Proper operation of the initiation relays is verified by de-energizing these the CHANNEL FUNCTIONAL TEST of the Actuation Logic This will actuate the Function, operating all associated equipment.
Proper operation of the equipment actuated by each train is thus verified.A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
A Note indicates this Surveillance includes verification of operation for each initiation relay.lIbe Frequency of[31]days is based on plant operating experience with regard to channel OPERABILITY, which demonstrates that failure of more than one channel of a given Function in any[31]day interval is a rare eve nt.....'",."....."."""'*"t''':'
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CEOG STS B 3.3.7-6 Rev.3.0, 03/31/04 CPlS (Analog) B 3.3.7 BASES SURVEILLANCE REQUIREMENTS (continued) CHANNEL CALIBRATION is a complete check of the instrument channel including the sensor. The Surveillance verifies that the channel responds to a measured parameter within the necessary range and accuracy. CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drift between successive calibrations to ensure that the channel remains operational between successive tests. CHANNEL CALIBRATIONS must be performed consistent with the plant specific setpoint analysis.
@e Frequency is based upon the assumption of an 1181 month calibration lnterval for the determination of the magnitude of equipment drift in the - Crr. W,".." ,<< setpoint analysis.
d;d;IIaV ]m6nths)&HANNEL FUNCTIONAL TEST is performed on the manual CPlS actuation circuitry.
A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions. This Surveillance verifies that the trip push buttons are capable of opening contacts in the Actuation Logic as designed, de-en gizing the initiation relays and providing Manual Trip of the Function.
f The 1181 month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power. Operating experience has shown these components usually pass the surveillance when performed at a Frequency of once
.- .--+"ll.uc every 18 months. T~ert I_C_- 2) CEOG STS B 3.3.7-7 Rev. 3.0, 03/31/04 CPIS (Analog)B 3.3.7 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.7.4 CHANNEL CALIBRATION is a complete check of the instrument channel including the sensor.The Surveillance verifies that the channel responds to a measured parameter within the necessary range and accuracy.CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drift between successive calibrations to ensure that the channel remains operational between successive tests.CHANNEL CALIBRATIONS must be performed consistent with the plant specific setpoint analysis.crEe Frequency is based upon the assumption of an[18]month calibration Interval for the determination of the magnitude of equipment drift in the setpoint analysis.(,
,,-'"..J-r\,.,:;e..r 1:-SR 3.3.7.5 E 8]..A1'6nths, I6HANNEL FUNCTIONAL TEST is performed on the manual C actuationcircuitry.A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
This Surveillance verifies that the trip push buttons are capable of opening contacts in the Actuation Logic as designed, the initiation relays and providing Manual Trip of the Function.Uhe[18]month Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power.Operating experience has shown these components usually pass the Surveillance when performed at a Frequency of once every 18 months.
CEOG STS B 3.3.7-7 Rev.3.0, 03/31/04 CPlS (Analog) B 3.3.7 BASES SURVEILLANCE REQUIREMENTS (continued) This Surveillance ensures that the train actuation response times are less than or equal to the maximum times assumed in the analyses.
ghe 18 month Frequency is based upon plant operating experience, which shows random failures of instrumentation components causing serious occurrences channel. REFERENCES 1 FSAR, Section [6.2]. 2. FSAR, Section 17.31. 3. "Plant Protection Svstem Selection of Trip Setpoint Values." CEOG STS Rev. 3.0, 03/31/04 CPIS (Analog)B 3.3.7 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.7.6 This Surveillance ensures that the train actuation response times are less than or equal to the maximum times assumed in the analyses.IThe 18 month Frequency is based upon plant operating experience, which shows random failures of instrumentation components causing serious response time de radation, but not chann ilure infr n occurrences.
Testing of the final actuating devices, which make up the bulk of the response time, is included.Testing of the final actuating device in one channel is included in the testing of each actuation logic channel.REFERENCES 1.FSAR, Section[6.2).2.FSAR, Section[7.3).3."Plant Protection System Selection of Trip Setpoint Values." CEOG STS B 3.3.7-8 Rev.3.0, 03/31/04 CRlS (Analog) B 3.3.8 BASES -- ACTIONS (continued) Required Action EC.2.21 is modified by a Note to indicate that normal plant control operations that individually add limited positive reactivity (e.g., temperature or boron fluctuations associated with RCS inventory management or temperature control) are not precluded by this Action, provided they are accounted for in the calculated SDM. SURVEILLANCE SR 3.3.8.1 REQUIREMENTS Performance of the CHANNEL CHECKGnce Merfl2 hour9 ensures that a gross failure of instrumentation has not occurred. A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels. It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value. Significant deviations between the two instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more serious. CHANNEL CHECK will detect gross channel failure; thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION. Agreement criteria are determined by the plant staff based on a combination of the channel instrument uncertainties, including indication and readability.
If a channel is outside the criteria, it may be an indication that the transmitter or the signal processing equipment has drifted outside its limit.
Ge Frequency, about once every shift, is based on operating experience that demonstrates the rarity of channel failure. Since the probability of two random failures in redundant channels in any 12 hour period is low, the CHANNEL CHECK minimizes the chance of loss of protective function due to failure of redundant channels. The CHANNEL CHECK supplements less formal, but more frequent, checks of channel OPERABILITY during normal operational use of the displavs associated -
* with the LC0 required channels.
Ln GSe vt 2) At this unit, the following administrative controls and design features (e.g., downscale alarms) immediately alert operations to loss of function in the nonredundant channels.
[ At this unit, verification of sample system alignment and operation for gaseous, particulate, and iodine monitors is required as follows:
] CEOG STS B 3.3.8-5 Rev. 3.0, 03/31/04 CRIS (Analog)B 3.3.8 BASES ACTIONS (continued)
Required Action[C.2.2]is modified by a Note to indicate that normal plant control operations that individually add limited positive reactivity (e.g., temperature or boron fluctuations associated with RCS inventory management or temperature control)are not precluded by this Action, provided they are accounted for in the calculated SOM.SURVEILLANCE REQUIREMENTS SR 3.3.8.1 Performance of the CHANNEL CHECK6i\Ce EWert12 hoUWensures that a gross failure of instrumentation has not occurred.A CHANNEL CHECK is normally a comparison of the parameter indicated on one channel to a similar parameter on other channels.It is based on the assumption that instrument channels monitoring the same parameter should read approximately the same value.Significant deviations between the two instrument channels could be an indication of excessive instrument drift in one of the channels or of something even more serious.CHANNEL CHECK will detect gross channel failure;thus, it is key to verifying the instrumentation continues to operate properly between each CHANNEL CALIBRATION.
Agreement criteria are determined by the plant staff based on a combination of the channel instrument uncertainties, inclUding indication and readability.
If a channel is outside the criteria, it may be an indication that the transmitter or the signal processing equipment has drifted outside its limit.u;,e Frequency, about once every shift, is based on operating experience that demonstrates the rarity of channel failure.Since the probability of two random failures in redundant channels in any 12 hour period is low, the CHANNEL CHECK minimizes the chance of loss of protective function due to failure of redundant channels.The CHANNEL CHECK supplements less formal, but more frequent, checks of channel OPERABILITY during normal operational use of the displays associated with the LCO required channels.
At this unit, the following administrative controls and design features (e.g., downscale alarms)immediately alert operations to loss of function in the nonredundant channels.[At this unit, verification of sample system alignment and operation for gaseous, particulate, and iodine monitors is required as follows:]CEOG STS B 3.3.8-5 Rev.3.0, 03/31/04 CRlS (Analog) B 3.3.8 BASES SURVEILLANCE REQUIREMENTS (continued) A CHANNEL FUNCTIONAL TEST is performed on the required control room radiation monitoring channel to ensure the entire channel will perform its intended function.
A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint analysis.
The as found and as left values must also be recorded and reviewed for consistency with the assumptions of the frequency extension analysis. The requirements for this review are outlined in Reference
[4]. @e Frequency of [92] days is based on plant operating experience with regard to channel OPERABILITY and drift, which demonstrates that failure of more than one channel of a given Function in any [92] day interval is a rare event.
-- Proper oweration of the individual initiation relavs is verified bv de- energizing these relays duri e CHANNEL FUNCTIONAL
?EST of the Actuation Logiqev- This will actuate the Function, operating
-- all associated equipment. Proper operation of the equipment actuated by each train is thus verified.
A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.
This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay. This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
Ehe Frequency of
[31] days is based on plant operating experience with regard to channel OPERABILITY, which demonstrates that failure of more than one channel of a given Function in any [31] days interval is a rare CEOG STS B 3.3.8-6 Rev. 3.0, 03/31/04 CRrs (Analog)B 3.3.8 BASES SURVEILLANCE REQUIREMENTS (continued)
SR 3.3.8.2 A CHANNEL FUNCTIONAL TEST is performed on the required control room radiation monitoring channel to ensure the entire channel will perform its intended function.A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
Any setpoint adjustment shall be consistent with the assumptions of the current plant specific setpoint analysis.The as found and as left values must also be recorded and reviewed for consistency with the assumptions of the frequency extension analysis.The requirements for this review are outlined in Reference[4].[he Frequency of[92]days is based on plant operating experience with regard to channel OPERABILITY and drift, which demonstrates that failure of more than one channel of a given Function in any[92]day interval is a rare event.
;:
'*..J,-nSe.r'SR 3.3.8.3 Proper operation of the individual initiation relays is verified byenergizing these CHANNEL FUNCTIONAL TEST of the Actuation Logic@Ov Ja This will actuate the Function, operating all associated equipment.
Proper operation of the equipment actuated by each train is thus verified.A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
Uhe Frequency of[31]days is based on plant operating experience with regard to channel OPERABILITY, which demonstrates that failure of more than one channel of a given Function in any[31]days interval is a rare event.4:----cr.n.s e..CEOG STS B 3.3.8-6 Rev.3.0, 03/31/04 CRlS (Analog) B 3.3.8 BASES -- SURVEILLANCE REQUIREMENTS (continued)
Note I indicates this Surveillance includes verification of operation for each initiation relay.
Note 2 indicates that relays that cannot be tested at power are excepted from the Surveillance Requirement while at power. These relays must, however, be tested during each entry into MODE 5 exceeding 24 hours unless they have been tested within the previous 6 months. CHANNEL CALIBRATION is a complete check of the instrument channel including the sensor. The Surveillance verifies that the channel responds to a measured parameter within the necessary range and accuracy.
CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drift between successive calibrations to ensure that the channel remains operational between successive surveillances.
CHANNEL CALIBRATIONS must be performed consistent with the plant specific setpoint analysis.
The as found and as left values must also be recorded and reviewed for consistency with the assumptions of the surveillance interval extension analysis.
The requirements for this review are outlined in Reference
[4]. Ee Frequency is based upon the assumption of an [I81 month calibration interval for the determination of the magnitude of equipment drift in the setpoint analysis.
4 . SR 3.3.8.5  very fi-?CHANNEL FUNCTIONAL TEST is performed on the manual CRlS actuation circuitry. A successful test of the required contact(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay. This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay.
This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
CEOG STS B 3.3.8-7 Rev. 3.0, 03/31/04 CRIS (Analog)B 3.3.8 BASES SURVEILLANCE REQUIREMENTS (continued)
Note 1 indicates this Surveillance includes verification of operation for each initiation relay.Note 2 indicates that relays that cannot be tested at power are excepted from the Surveillance Requirement while at power.These relays must, however, be tested during each entry into MODE 5 exceeding 24 hours unless they have been tested within the previous 6 months.SR 3.3.8.4 CHANNEL CALIBRATION is a complete check of the instrument channel including the sensor.The Surveillance verifies that the channel responds to a measured parameter within the necessary range and accuracy.CHANNEL CALIBRATION leaves the channel adjusted to account for instrument drift between successive calibrations to ensure that the channel remains operational between successive surveillances.
CHANNEL CALIBRATIONS must be performed consistent with the plant specific setpoint analysis.The as found and as left values must also be recorded and reviewed for consistency with the assumptions of the surveillance interval extension analysis.The requirements for this review are outlined in Reference[4].IT;e Frequency is based upon the assumption of an[18]month calibration interval for the determination of the magnitude of equipment drift in the setpoint analysis.'!.,." , ,.**"Z'.", Y"iSe.w'**
4.,)
SR 3.3.8.5<gyery 118]
4HANNEL FUNCTIONAL TEST is performed on the manual CRIS actuation circuitry.
A successful test of the required contaet(s) of a channel relay may be performed by the verification of the change of state of a single contact of the relay.This clarifies what is an acceptable CHANNEL FUNCTIONAL TEST of a relay.This is acceptable because all of the other required contacts of the relay are verified by other Technical Specifications and non-Technical Specifications tests at least once per refueling interval with applicable extensions.
CEOG STS B 3.3.8-7 Rev.3.0, 03/31/04 BASES CRlS (Analog) B 3.3.8 - -. . - - SURVEILLANCE REQUIREMENTS (continued) This test verifies that the trip push buttons are capable of opening contacts in the Actuation Logic as designed, de-energizing the initiation relays and providing Manual Trip of the function.ahe
[I81 rponth Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance were performed with the reactor at power. Operating experience has shown these components usually pass
-. the ~urveillance when perforrnedfiaFrequency of once every
[I 81 months. Mnserta [SR 3.3.8.6 This Surveillance ensures that the train actuation res onse times are less than the maximum times assumed in the analyses.
fhe [I 81 month Frequency is based upon plant operating experience, which shows that random failures of instrumentation components causing serious response time degradation, but not channel failure, are infrequent occurrences. Testing of the final actuating devices, which make up the bulk of the response time, is included in the Surveillance testing. ] fl 3 REFERENCES
: 1. FSAR, Chapter
[I 51. yzn 3;-0 2. "Plant Protection System Selection of Trip Setpoint Values." 3. 10 CFR 50, Appendix A, GDC 19. CEOG STS Rev. 3.0, 03/31/04 CRIS (Analog)B 3.3.8 BASES SURVEILLANCE REQUIREMENTS (continued)
This test verifies that the trip push buttons are capable of opening contacts in the Actuation Logic as designed, de-energizing the initiation relays and providing Manual Trip of the function.[the[18J"Ilonth Frequency is based on the need to perform this Surveillance under the conditions that apply during a plant outage and the potential for an unplanned transient if the Surveillance wereperformedwith the reactor at power.Operating experience has shown these components usually pass the Surveillance when perf9.rmed at a Frequency of once every[18]months.
[SR 3.3.8.6 FSAR, Chapter[15].This Surveillance ensures that the train actuation times are less than the maximum times assumed in the analyses.\!..he[18]month Frequency is based upon plant operating experience, which shows that random failures of instrumentation components causing serious response time degradation, but not channel failure, are infrequent occurrences.
C'\Testing of the final actuating devices, which make up the bulk of the.../response time, is included in the Surveillance testing.}1.REFERENCES 2."Plant Protection System Selection of Trip Setpoint Values." 3.10 CFR 50, Appendix A, GOC 19.4.[}.CEOG STS B 3.3.8-8 Rev.3.0, 03/31/04}}

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