Text

Proposed Tech Specs Changes,Revising Feedwater Isolation ESFAS Functions in TS Tables 3.3-3,3.3-4 & 4.3-2
	ML20198F391
Person / Time
Site:	Callaway
Issue date:	08/08/1997
From:	; UNION ELECTRIC CO.
To:	;
Shared Package
ML20198F372	List: ML20198F391; ULNRC-03628, Application for Amend to License NPF-30,revising Feedwater Isolation ESFAS Functions in TS Tables 3.3-3,3.3-4 & 4.3-2 as Listed;
References
	NUDOCS 9708130030
	Download: ML20198F391 (16)
	v • d • e

. . .. .. ... . . . .

ULNRC-03628 ATTAC11 MENT FOUR CIIANGES TO ULNRC-3578 ATTACIIMENT 19 9708130030 970808 I PDR ADOCK 05000483 .-

p. PDR

ESFAS Instrumentation 3.3.2 ACTIONS (continued)

CONDITION REPslRED ACTION COMPLETION TIME G. One train inoperable. G.1 NOTE -

One train may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing provided the other train is OPERABLE.

..........e.................

Restore train to OPERABLE 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months status.

DB G.2.1 Be in H0DE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ANQ G.2.2 Be in H00E 4. 18 hours2.083333e-4 days 0.005 hours 2.97619e-5 weeks 6.849e-6 months p.

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! .2 wC in b w. 2 99"E (continued) j

)

CALLAWAY PL%'T ITS 3.3 24 5/15/97

ESFAS Instrumentation 3.3.2 Table 3.3.2 1 (page 3 of C)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE.

MODES OR OTER-SPECIFIED REQUIRED $URVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIRE S TS VALUE"'

4. Steam Line Isolation (continued) l

c. Aatomatic Actuation 1. 2i" 3'" 2 G SR 3.3.2.13 NA Logic and Actuation trains">

Relays (MSFIS)

d. Contairment 1.2i". 3"' 3 D SR 3.3.2.1 s 18.3 psig Pressure - High 2 SR 3.3.2.5 SR 3.3.2,9

c. Steam Line Pressure (1) Low 1.2 '". 3 per D SR 3.3.2.1 a 571 psig"'

3*"" steam SR 3.3.2.5 line SR 3.3.2.9 (2) Negative 34"" 3 per D SR 3.3.2.1 s 124*' psi Rate - High steam SR 3.3.2.5 line SR 3.3.2.9

5. Turbine Trip and Feedwater Isolation

4. Automatic Actuation 1.2u;3 h 2 trains =99- 6 SR 3.3.2.2 NA Logic and Actuation SR 3.3.2.4 Relays (SSPS) SR 3.3.2.6*'

b. Automatic Actuation 1. 2u' 7 b 2 u- $ SR 3.3.2.13 NA Logic and Actuation 2 trains">

Relays (MSFIS)

(continued)

(a) The Allwable value defines the limiting safety system setting. See the Bases for the Trip Setpoints.

(b) Above the P 11 (Pressurizer Pressure) Interlock.

(c) Time constants used in the lead / lag controller are si a 50 seconds and t, s 5 sends.

(g) Belm the P.11 (Pressurizer Pressure) Interlock; however, may be blocked below P 11 when safety injection on low steam line pressure is not blocked.

(h) Time constant utilized in the ratellag controller is a 50 seconds.

(1) Except when all MSIVs are closed.

(j) Except when all MFIVs are closed.

(o) Each train requires a minimum of two programable logic controllers to be OPERABLE.

= (p) Except-relay K620 which shall be tested every 18 months; and prior to entering M00E-e whenever the unit has been in MODE 5 or 6 for > 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . if not performed within the previous 90 days. 4 3

CALLAWAY-PLANT ITS 3.3 35 5/15/97 l

_A

ESFAS Instrumentation 3.3.2-Table 3.3.21 (page 4 of 6)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR-DTHER SPECIFIED REQUIRED SURVEILLhCE ALLOWABLE FijNCTION ' CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE"'

5 Turbine Trip and Fee &ater Isolation (continued)

c. SG Water Level- High 1.25 4 per SG -1 SR 3.3.2.1 s 79.8% of High (P.14) SR 3.3.2.5 Narrow Range SR 3.3.2.9 Instrument Span

d. Safety injection Refer to Function 1 (Safety injection) for all initiation functions and requirements.

6, Auxiliary Feedwater

a. Manual Initiation 1, 2, 3 1/pung Q SR 3.3.2.8 NA

b. Automatic Actuation 1.2.3 2 trains G SR 3.3,2.2 NA Logic and Actuation SR 3.3.2.4 Relays (SSPS) SR 3.3.2.6

c. Automatic Actuation 1,2,3 2 trains R- SR 3.3.2.3 NA Logic and Actuation Relays (BOP ESFAS)

d. SG Water Level Lou. Low (1) Steam Generator 1.2,3 4 per SG D SR 3.3.2.1 a 18.4% of Water Level Low- SR 3.3.2.5 Narrw Range L w (Adverse SR 3.3.2.9 Instrument Contairment Span Environment)-

(2) Steam Generator 1,2,3 4 per SG N SR 3.3.2.1 a 13.0% of WaterLevel SR 3.3.2.5 Narr w Range Low Low (Nonnal SR 3.3.2.9 Instrument Containment Span Environment)

(continued)-

(a) The Allowable Value defines the limiting safety system setting. See the Bases for the Trip Setpoints.

(j) Except when all HFlys are closed.

CALLAWAY PLANT ITS 3.3 36 5/15/97

INSERT 3.3-36 APPLICABLE h10 DES OR OTilER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS Cf!ANNELS CONDITIONS REQUIREhtENTS VALUE 5.e Steam Generator Water Level Low-Lown (1) Steam Generator 1, 29, 3W 4 per SG D SR 3.3.2.1 218.4% of Water Level Low Low SR 3.3.2.5 Narrow Range (Adverse Containment SR 3.3.2.9 Instrument Environment) Span (2) Steam Generator 1, 2W, 39 4 per SG N SR 3.3.2.1 113.0% of Water Level Low Low SR 3.3.2.5 Narrow Range

! (Normal Containment SR 3.3.2.9 Instrument Environment) Span (3) Vessel AT 1, 2W 4 h1 SR 3.3.2.1 Equivalent and SR 3.3.2.5 Trip Time Delay SR 3.3.2.9 (a) Vessel AT $ Vessel AT Equivalent Equivalent 510% RTP to 13.9%

Vessel AT RTP*

(Power 1)

(b) 10% RTP < $ Vessel AT Vessel AT Equivalent Equivalent

~

to 23.9%

5 20% RTP RTFD Vessel AT (Power-2)

(4) Containment 1, 2*, 3W 4 O SR 3.3.2.1 5 2.0 psig Pressure - SR 3.3.2.5 Environmental SR 3.3.2.9 Allowance hiodifier (j) Except when all hiFIVs are closed.

(k) With a time delay 5 240 seconds.

(1) With a time delay 5130 seconds.

(q) Fcedwater isolation only.

UIRRC-03628 ATTACIIAIENT FIVF CIIANGES TO UIERC-3578 ATT CIIAIENT 20 I

B

ESFAS Instrumentation-B 3.3.2

)- BASES APPLICABLE 5. Turbine Trio and Feedwater Isolation (continued)

SAFETY ANALYSES, LCO,-and .

Trips the HFW pumps, closing the pump discharge-APPLICABILITY valves; and Initiates feedwater isolation.

This Function is actuated by SG Water Level High High, or by an SI signal. The RTS also initiates a turbine trip signal whenever_ a reactor trip:(P 4) is generated. In the event of SI the unit is taken off line and the turbine generator must be tripped. The HFW System is also taken out of operation and the AFW System is automatically started. The SI signal was previously discussed.

.ZN M T f T.3-90

a. Turbine Trio and Feedwater Isolation Automatic Actuation Loaic and Actuation Relavs (SSPS)

- Automatic Actuation Logic and Actuation Relays' in the SSPS consist of the same features and operate in the same manner as described for ESFAS Function 1.b.

b, Feedwater Isolation Automatic Actuation Loaic and Act"ation Relays (HSFIS)

-Automatic' Actuation Logic and Actuation Relays in the HSFIS consist of the same features and operate in the same manner as described for ESFAS Function 4.c.

c. Turbine Trio and Feedwater Isolation Steam Generator Water Level Hiah Hiah (P 14)

This signal provides protection against excessive feedwater flow. The ESFAS-SG water level instruments provide input to the SG Water Level Control System. Therefore, the actuation logic must be able to withstand both an input failure to the control system (which may then require the protection _ function actuation)'and a single failure in the other channels providing the protection function actuation. Thus,- four OPERABLE channels per SG are required to satisfy the requirements with (continued)

CALLAWAY PLANT ITS - BASES B 3.3 90 5/15/97

INSERT B 3.3 90 While the above discussion applies to both tmbine trip and feedwater isolation in response to excessive feedwater in MODES 1 and 2, feedwater isolation on SG low-low level is required for events in MODES 1,2, and 3 where the assurance of AFW delivery to the intact steam generators is paramount in the accident analysis. The analyses for the Loss of Non-Emergency AC Power, Loss of Nonnal Feedwater, and Feedwater System Pipe Break events credit feedwater isolation on SG low-low level. Given the location of the feedwater -

check valves inside containment downstream of the point where AFW connects to the main feedwater piping, closure of the main feedwater isolation valves (MFIVs)is required to assure AFW flow is not diverted. The Applicable MODES for the feedwater isolation function on SG low-low level are consistent with those for the MFIVs (LCO 3.7.3) and AFW System (LCO 3.7.5).

ESFAS Instrumentation B 3.3.2

) BASES APPLICABLE c Turbine Trio and Feedwater Isolation Steam SAFETY ANALYSES, Generator Water Level Hioh Hioh (P 14)

LCO, and (continued)

APPLICABILITY a two out of four logic in any SG resulting in actuation signal generation.

The transmitters (d/p cells) are located inside containment. However, the events that this function protects against cannot cause a severe environment in containment. Therefore, the Trip Setpoint reflects only steady state instrument uncertainties.

The Trip Setpoint is s 78% of narrow range span.

d, Turbine Trio and Feedwater Isolation Safety In_iection Turbine Trip and Feedwater Isolation are also initiated by all Functions that initiate SI. The Feedwater Isolation Function requirements for these Functions are the same as the requirements for their

) SI function. Therefore, the requirements are not repeated in Table 3.3.21. Instead Function 1, SI, is referenced for all initiating functions and

! requirements,

" fc J'6 Wa b

.1meRT e z 2AI Lakt-Mgklif Turbine Trip and Feedwater Isolation Functiond ust be OPERABLE in MODES 1 and 2 except when all HFIVs a g* ,

closed. In H0 DES 3, 4. 5, and 6 Functio s not required to be OPERABLE. A// of 8- FuneMae J,veexuefla ofFAhtW in h an a// thFXVe 6, Auxiliary Feedwater thobEr are ,/}/,fa

L excaf ad w;f exey/- WAan a//

M F;r Vs e e elus2.

The AFW System is designed to provide a secondary side heat sink for the reactor in the event that the HFW System is not available. The system has two motor driven pumps and a turbine driven pump. making it available during normal unit operation, during a loss of AC power, a loss of HFW, and during a Feedwater System pipe break. The normal source of water for the AFW System is the condensate storage tank (CST). A loss of suction pressure, coincident with an auxiliary feedwater actuation signal (AFAS) will automatically realign the pump (continued)

CALLAWAY PLANT ITS BASES B 3.3 91 5/15/97 j

INSERT B 3.3-91 (Page 1 of 2)

e. Feedwater Isolation - Steam Generator Water Level - Low Low SG Water Level - Low Low provides protection against a loss of heat sink by ensuring the isolation of normal feedwater and AFW delivery to the steam generators, given the location of the feedwater line check i valves. A feedwater line break or a loss of MFW would result in a loss of SG water level. SG Water Level - Low Low provides input to the SG Level Control System. Therefore, the actuation logic must be able to L withstand both an input failure to the control system which may then L require a protection function actuation and a single failure in the other channels providing the protection function actuation. Thus, four

[ OPERABLE channels are required to satisfy the requirements with two-out-of-four logic (the EAM and TTD functions also use a two-out-of-four logic). Two-out-of-four low level signals in any SG initiates feedwater isolation. As discussed in R.eference 11, the SG Water Level - Low Low trip function at Callaway has been modified to allow a lower Trip Setpoint under normal containment environmental conditions and a delayed trip when THERMAL POWER is less than or equal to 20% RTP.

This circuitry reduces the potential for inadvenent trips via the Environmental Allowance Modifier (EAM), dependent on containment pressure, and the Trip Time Delay (TTD), dependent on vessel AT (THERMAL POWER). With the transmitters (d/p cells) located inside containment and thus possibly experiencing adverse environmental conditions (due to a feedline break), the Environmental- Allowance Modifier (EAM) was devised. The EAM ftmetion senses the presence of adverse containment conditions (elevated pressure) and enables the Steam Generator Water Level - Low Low trip setpoint (Adverse) which reflects the increased transmitter uncertainties due to this environment. The EAM allows the use of a lower Steam Generator Water Level - -Low Low trip setpoint (Normal) when these conditions are not present, thus allowing more margin to trip for normal operating conditions. The Trip Time Delay (TTD) creates additional operating margin when the plant needs it most, during early escalation to power, by allowing the operator time to recover level when the primary side load is sufficiently small to allow such action.

- The TTD is based on the continuous monitoring of primary side power

INSERT B 3.3-91 (Page 2 of 2)

e. LFeedwater Isolation - Steam Generator Water Level - Low Low through the use of Vessel AT. Scaling of the Vessel AT chamels is dependent on the loop-specific values for ATo, discussed under the OTDT and OPDT trips. Two time delays are possible, based on the primary side power level, the magnitude of the trip delay decreasing with increasing power. In the event that the EAM or TTD functions do not meet the required channels, it is acceptable to place the inoperable channels in the tripped condition and continue operation. Placing the inoperable channels in this mode will result in the enabling of the Steam Generator Water L Level - Low Low (Adverse) function, for the EAM, or in the removal of the trip delay, for the TTD. In the event that the Steam Generator Water -

l Level - Low Low (Normal) function does not meet the required channels, the channels can be tripped or it is acceptable to place the associated EAM channels in the tripped condition and continue operation. Performing the latter action is preferred since a partial trip is avoided; however, this will result in the enabling of the Steam Generator Water Level - Low Low (Adverse) function which has a more conservative (higher level) trip '

setpoint. At this time it would also be acceptable to place the inoperable Steam Generator Water Level - Low Low (Normal) channels in the bypassed condition to prevent an inadvertent Reactor Trip or ESFAS.

actuation.

The Trip Setpoints reflect the inclusion of both steady state and adverse environment instrument uncertainties. The Trip Setpoints for the Steam Generator Water Level - Low Low (Adverse Containment Environment) and (Nonnal Containment Environment) bistables are 220.2% and 214.8% of narrow range span, respectively. The Trip Setpoints for the Vessel AT (Power 1) and (Power 2) bistables are $ Vessel AT Equivalent to.10% RTP and $ Vessel AT Equivalent to 20% RTP, respectively, with corresponding trip time delays of 5 232 seconds and $ 122 seconds. The Trip Setpoint for the Containment Pressure - Environmental Allowance Modifier bistables is s 1.5 psig.

l a

ESFAS Instrumentation B 3,3,2 BASES APPLICABLE a. Enaineered Safety Feature Actuation System SAFETY ANALYSES, Interlocks Reactor Trio. P 4 (continued)

LCO, and APPLICABILITY the noted Functions have been interlocked with P 4 as part of the design of the unit control and protection system. 'EM/ EAT 8 7,7-/4/

None of the noted Functions serves a mitigation function in the unit licensing basis safety analyses. Only the turbine trip Function is explicitly assumed since it is an immediate consequence of the reactor trip Function, Neither turbine trip, nor any of the other four Functions associated with the reactor trip signal, is required to show that the unit licensing basis safety analysis acceptance criteria are met, The RTB position switches that provide input to the P 4 interlockM ' ;ener:ted +: 09: tP':

M ~+ ^" m a Ped;r ;;d th; :lt;caut; tr;in*:

B;;;; Sr :hcr Orc b;th egen; only function to energize or de energize or open or close contacts,

Therefore, this Function has no adjustable trip setpoint with which to associate a Trip S tpoint and Allowable Value.

This Function must be OPERABLE in H0 DES 1, 2, and 3 when the reactor may be critical or approaching criticality,

b. Enm neered Safety Feature Actuation System Interlocks Pressurizer Pressure. P 11 The P 11 interlock permits a normal unit cooldown and depressurization without actuation of SI or main steam line isolation, With two out of three pressurizer pressure channels (discussed previously) less than the P 11 setpoint, the operator can manually block the Pressurizer Pressure-Low and Steam Line Pressure 'Aw SI signals and the Steam Line Pressure-Low steam line isolation signal (previously discussed), When the Steam Line Pressure-Low steam line isolation signal is 1

(continued)

CALLAWAY PLANT ITS BASES B 3,3 101 5/15/97

INSERT B 3.3-101 The feedwater isolation function on P-4 with coincident low T,, may be blocked using a bypass switch to prevent undue cycling of the FWlVs and AFW pumps. ,

ESFAS Instrumentation B 3.3.2 BASES

)

l ACTIONS F.1. F.2.1. and F.2.2 (continued). I 1

redundancy, and the low probability of an event occurring during j l

this interval. If the Function cannot be returned to OPERABLE status, the unit must be placed in H0DE 3 within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and H00E 4 within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , The allowed Completion '

i Times are reasonable, based on operating experience, to reach the required unit conditions from full power in an orderly manner and without challenging unit systems. In H0DE 4, the unit does not have any analyzed transients or conditions that require the explicit use of the protection functions noted above.

7bdine N/

a v{ fec h Y*r G.I. G.2.1 and G.2 J, f4 /a 4%

Condition G applies to the automatic actuation logic and actuation relays (SSPS) for the Steam Line Isolation %nd AFW

- actuation Functions. Condition G also applies to the MSFIS automatic actuation logic.

The action addresses the train orientation of the actuation logic q for these functions. If one train is inoperable, 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months are a allowed to restore the train to OPERABLE status. The Completion

- Time for restoring a train to OPERABLE status is reasonable considering that there is another train OPERABLE, and the low probability of an event occurring during this interval. If the train cannot be returned to OPERABLE status, the unit must be brought to MODE 3 within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and H00E 4 within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months . 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.

Placing the unit in H00E 4 removes all requirements for OPERABILITY of the protection channels and actuation functions.

In this H00E, the unit does not have analyzed transients or conditions that require the explicit use of the protection functions noted above.

The Required Actions are modified by a Note that allows one train to be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing !

provided the other train is OPERABLE. This allowance is based on l (continued)

)

CALLAWAY PLANT ITS BASES- B 3.3 108 5/15/97

ESFAS Instrumentation B 3.3.2 BASES

)

ACTIONS G.I. G.2.1 and G.2.2 (continued) the reliability analysis (Refs. 8 and l'O assumption that 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months is the average time required to perform channel surveillance.

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I.1 an11.2 Condition I applies to:

. SG Water Level-High High (P 14).

)

(continued)

CALLAWAY PLANT ITS BASES B 3.3 109 5/15/97

ESFAS Instrumentation B 3.3.2

') BASES SURVEILLANCE SR 3.3.2.4 (continued)

REQUIREMENTS 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. This test-is performed every

~

31 days on a STAGGERED TEST BASIS. The time allowed for the testing (4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months ) and the surveillance interval are justified in Reference 8.

SR 3.3.2.5 SR 3.3.2.5 is the performance of a COT.

l A COT is performed on each required channel to ensure the channel will perform the intended Function. Setpoints must be found within the Allowable Values specified in Table 3.3.21.

The setpoint shall be left set consistent with the asstaptions of

-the current unit specific setpoint methodology.

The Frequency of 92 days is justified in Reference 8.

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 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. This ted is performed every 92 days, except for relays K602. K620. K622. K624. K630. K740, and K741 which are tested once per 18 months and prior to entering Function Applicability (MODE 4 for Functions 1.b. 3.a.(2), and 7.a: H00E-G-3 for Function 5.a in Table 3.3.21) whenever the unit has been in H0DE 5 or 6 for > 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . if not performed within the previous (continued)

CALLAWAY PLANT ITS BASES B 3.3 117 5/15/97 I

1 A

ML20198F391

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